Magnum Hunter Resources 10-K 25 Feb 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 18, 2014	Jun. 30, 2013
Document And Entity Information	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Entity Registrant Name	'Magnum Hunter Resources Corp	'	'
Entity Central Index Key	'0001335190	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$585,926,716
Entity Common Stock, Shares Outstanding	'	171,910,067	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
CURRENT ASSETS	'	'
Cash and cash equivalents	$41,713,000	$57,623,000
Restricted cash	5,000,000	1,500,000
Accounts receivable, net of allowance for doubtful accounts of $292 and $448 as of December 31, 2013 and 2012, respectively	55,681,000	124,861,000
Derivative assets	608,000	5,146,000
Inventory	7,158,000	9,162,000
Investments	2,262,000	3,278,000
Prepaid expenses and other assets	2,938,000	2,249,000
Assets held for sale	5,366,000	500,000
Total current assets	120,726,000	204,319,000
PROPERTY, PLANT AND EQUIPMENT	'	'
Oil and natural gas properties, successful efforts method of accounting	1,355,288,000	1,908,659,000
Accumulated depletion, depreciation, and accretion	-130,629,000	-186,156,000
Total oil and natural gas properties, net	1,224,659,000	1,722,503,000
Gas transportation, gathering and processing equipment and other, net	289,420,000	201,910,000
Total property, plant and equipment, net	1,514,079,000	1,924,413,000
OTHER ASSETS	'	'
Deferred financing costs, net of amortization of $12,842 and $8,024 as of December 31, 2013 and 2012, respectively	20,008,000	23,862,000
Derivatives assets	25,000	0
Intangible assets, net	6,530,000	8,981,000
Goodwill	30,602,000	30,602,000
Other assets	1,994,000	6,455,000
Assets held for sale	162,687,000	0
Total assets	1,856,651,000	2,198,632,000
CURRENT LIABILITIES	'	'
Current portion of notes payable	3,804,000	3,991,000
Accounts payable	107,860,000	196,515,000
Accrued liabilities	44,629,000	11,212,000
Revenue payable	6,313,000	20,394,000
Derivatives liabilities	1,903,000	3,501,000
Other liabilities	6,491,000	8,043,000
Liabilities associated with assets held for sale	12,865,000	0
Total current liabilities	183,865,000	243,656,000
Long-term debt	876,106,000	886,769,000
Asset retirement obligation	16,163,000	28,322,000
Deferred tax liability	0	74,258,000
Derivative liabilities	76,310,000	47,524,000
Other long-term liabilities	2,279,000	5,573,000
Liabilities associated with assets held for sale	14,523,000	0
Total liabilities	1,169,246,000	1,286,102,000
COMMITMENTS AND CONTINGENCIES (Note 18)	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	236,675,000	200,878,000
SHAREHOLDERS' EQUITY:	'	'
Common stock	1,724,000	1,700,000
Additional paid in capital	733,753,000	715,033,000
Accumulated deficit	-586,365,000	-307,484,000
Accumulated other comprehensive loss	-19,901,000	-8,889,000
Treasury Stock, at cost	-1,914,000	-1,914,000
Total Magnum Hunter Resources Corporation shareholders' equity	441,580,000	701,513,000
Non-controlling interest	9,150,000	10,139,000
Total shareholders' equity	450,730,000	711,652,000
Total liabilities and shareholders’ equity	1,856,651,000	2,198,632,000
Series C Cumulative Perpetual Preferred Stock	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	100,000,000	100,000,000
Series A Convertible Preferred Units	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	136,675,000	100,878,000
Series D Cumulative Preferred Stock	'	'
SHAREHOLDERS' EQUITY:	'	'
Preferred stock	221,244,000	210,441,000
Series E Cumulative Convertible Preferred Stock	'	'
SHAREHOLDERS' EQUITY:	'	'
Preferred stock	95,069,000	94,371,000
Treasury Stock, at cost	-2,030,000	-1,750,000
Exchangeable common stock	'	'
SHAREHOLDERS' EQUITY:	'	'
Common stock	$0	$5,000

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Series C Cumulative Perpetual Preferred Stock

Series C Cumulative Perpetual Preferred Stock

Series A Convertible Preferred Units

Series A Convertible Preferred Units

Series D Cumulative Preferred Stock

Series D Cumulative Preferred Stock

Series E Cumulative Convertible Preferred Stock

Series E Cumulative Convertible Preferred Stock

Series E Cumulative Convertible Preferred Stock

Exchangeable common stock

Exchangeable common stock

Accounts receivable, allowance for doubtful accounts (in dollars)

$292,000

$448,000

'

'

'

'

'

'

'

'

'

'

'

Amortization of deferred financing costs (in dollars)

12,842,000

8,024,000

'

'

'

'

'

'

'

'

'

'

'

Cumulative dividend rate for Series C Cumulative and Series A Convertible Preferred Stock (as a percent)

'

'

10.25%

10.25%

8.00%

8.00%

'

'

'

'

'

'

'

Preferred stock, shares authorized

'

'

4,000,000

4,000,000

'

'

'

'

'

'

'

'

'

Preferred Stock, shares issued

'

'

4,000,000

4,000,000

9,885,048

7,672,892

'

'

'

'

'

'

'

Preferred Stock, shares outstanding

'

'

4,000,000

4,000,000

9,885,048

7,672,892

'

'

'

'

'

'

'

Preferred Stock, liquidation preference (in dollars per share)

'

'

$25

$25

'

'

'

'

'

'

'

'

'

Preferred Stock, liquidation preference

'

'

'

'

$200,620

$167,403

'

'

'

'

'

'

'

Preferred Stock, shares authorized

1,000,000

10,000,000

'

'

'

'

5,750,000

5,750,000

12,000

12,000

12,000

'

'

Cumulative dividend rate for cumulative preferred stock (as a percent)

'

'

10.25%

'

'

'

8.00%

8.00%

8.00%

8.00%

8.00%

'

'

Preferred Stock, shares issued

'

'

'

'

'

'

4,424,889

4,208,821

3,775

3,803

3,775

'

'

Preferred Stock, shares outstanding

'

'

'

'

9,885,048

'

4,424,889

4,208,821

3,705

3,722

3,705

'

'

Preferred Stock, liquidation preference (in dollars per share)

'

'

'

'

'

'

$50

$50

$25,000

$25,000

$25,000

'

'

Common stock, par value (in dollars per share)

$0.01

$0.01

'

'

'

'

'

'

'

'

'

$0.01

$0.01

Common stock, shares authorized

350,000,000

250,000,000

'

'

'

'

'

'

'

'

'

'

'

Common stock, shares issued

172,409,023

170,032,999

'

'

'

'

'

'

'

'

'

505,835

505,835

Common stock, shares outstanding

171,494,071

169,118,047

'

'

'

'

'

'

'

'

'

505,835

505,835

Treasury stock, shares

914,952

914,952

'

'

'

'

'

'

70

81

70

'

'

Unearned common stock in KSOP

0

0

'

'

'

'

'

'

'

'

'

'

'

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
REVENUES AND OTHER	'		'		'
Oil and natural gas sales	$197,599		$114,659		$58,726
Natural gas transportation, gathering, processing, and marketing	60,632		13,040		494
Oilfield services	18,431		12,333		7,149
Other revenue	3,749		324		86
Total revenue	280,411		140,356		66,455
OPERATING EXPENSES	'		'		'
Lease operating expenses	53,961		26,839		14,998
Severance taxes and marketing	17,721		7,854		5,341
Exploration	97,342		78,221		2,605
Natural gas transportation, gathering, processing, and marketing	52,099		8,028		373
Oilfield services	14,825		10,037		6,759
Impairment of proved oil and gas properties	9,968		3,772		0
Depreciation, depletion, amortization and accretion	99,198		59,730		23,246
Loss on sale of assets, net	44,654		628		361
General and administrative	75,407		53,454		54,360
Total operating expenses	465,175		248,563		108,043
OPERATING LOSS	-184,764		-108,207	[1]	-41,588
OTHER INCOME (EXPENSE)	'		'		'
Interest income	220		199		10
Interest expense	-72,423		-51,616		-11,752
Gain (loss) on derivative contracts, net	-25,274		22,239		-6,346
Other income (expense)	7,892		-1,583		0
Total other expense, net	-89,585		-30,761		-18,088
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-274,349		-138,968		-59,676
Income tax benefit (expense)	70,297		19,312		2,862
LOSS FROM CONTINUING OPERATIONS	-204,052		-119,656		-56,814
Loss from discontinued operations, net of tax	-71,131	[2]	-19,474		-19,598
Gain on disposal of discontinued operations, net of tax	52,019	[3],[4],[5]	2,409	[4],[5]	0	[4],[5]
NET LOSS	-223,164		-136,721		-76,412
Net loss (income) attributable to non-controlling interest	988		4,013		-249
NET LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-222,176		-132,708		-76,661
Dividends on preferred stock	-56,705		-34,706		-14,007
NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS	-278,881		-167,414		-90,668
Weighted average number of common shares outstanding, basic and diluted	170,088,108		155,743,418		113,154,270
Loss from continuing operations per share, basic and diluted	($1.53)		($0.96)		($0.63)
Income (loss) from discontinued operations per share, basic and diluted	($0.11)		($0.11)		($0.17)
NET LOSS PER COMMON SHARE, BASIC AND DILUTED	($1.64)		($1.07)		($0.80)
Loss from continuing operations, net of tax	-203,064		-115,643		-57,063
Income (loss) from discontinued operations, net of tax	($19,112)		($17,065)		($19,598)
[1]	The quarter-ended December 31, 2012, loss from operations was primarily driven by exploration expense. During the quarter-ended December 31, 2012 management determined that a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return in 2013.
[2]	The quarter-ended September 30, 2013, loss from discontinued operations was primarily driven by impairment expense of $72.5 million, as management determined a significant portion of the non-core acreage would not be utilized.
[3]	The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".
[4]	Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.
[5]	The Companybs effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Other Comprehensive Income [Abstract]	'	'	'
NET LOSS	($223,164)	($136,721)	($76,412)
OTHER COMPREHENSIVE INCOME (LOSS)	'	'	'
Foreign currency translation gain (loss)	-10,928	3,883	-12,477
Unrealized gain (loss) on available for sale investments	8,178	-309	14
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	-8,262	0	0
Total other comprehensive income (loss)	-11,012	3,574	-12,463
COMPREHENSIVE LOSS	-234,176	-133,147	-88,875
Comprehensive (income) loss attributable to non-controlling interests	988	4,013	-249
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	($233,188)	($129,134)	($89,124)

CONSOLIDATED_STATEMENT_OF_SHAR

CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY (USD $)

Total

Common Stock

Exchangeable Common Stock

Additional Paid in Capital

Accumulated Deficit

Accumulated Other Comprehensive Loss

Treasury Stock

Unearned Common Shares in KSOP

Non-controlling Interest

Series D Preferred Stock

Series D Preferred Stock

Series E Preferred Stock

In Thousands, except Share data, unless otherwise specified

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Preferred Stock

Preferred Stock

USD ($)

USD ($)

BALANCE at Dec. 31, 2010

$103,322

$749

$0

$152,439

($49,402)

$0

($1,310)

($604)

$1,450

'

$0

$0

BALANCE (in shares) at Dec. 31, 2010

'

74,863,000

0

'

'

'

'

'

'

'

0

0

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

Share based compensation (in shares)

'

121,000

'

'

'

'

'

'

'

'

'

'

Share based compensation

25,057

1

'

25,056

'

'

'

'

'

'

'

'

Issued shares of Common Stock for payment of commitment fee and services for the year ended December 31, 2011 and 2010, respectively (in shares)

'

166,000

'

'

'

'

'

'

'

'

'

'

Issued shares of Common Stock for payment of commitment fee and services for the years ended December 31, 2011 and 2010, respectively

779

2

'

777

'

'

'

'

'

'

'

'

Issued shares of stock for cash (in shares)

'

1,714,000

'

'

'

'

'

'

'

1,437,558

'

'

Issued shares of Common Stock for cash

13,892

17

'

13,875

'

'

'

'

'

'

'

'

Issued shares of Preferred Stock for Cash (in cash)

'

'

'

'

'

'

'

'

'

'

1,438,000

'

Issued shares of Preferred Stock for cash

65,000

'

'

-6,878

'

'

'

'

'

'

71,878

'

Issued shares of Common Stock upon exercise of warrants and options (in shares)

'

6,293,000

'

'

'

'

'

'

'

'

'

'

Issued shares of Common Stock upon exercise of warrants and options

7,618

63

'

7,555

'

'

'

'

'

'

'

'

Preferred dividends

-14,007

'

'

'

-14,007

'

'

'

'

'

'

'

Issued 12,875,093 warrants for payment of dividends on common stock with fair market value of $6.7 million

0

'

'

'

'

'

'

'

'

'

'

'

Issued 378,174 warrants for payment of dividends on MHR Exchangeco Corporation's exchangeable common stock with fair market value of $197 thousand

0

'

'

'

'

'

'

'

'

'

'

'

Issued shares of common stock for acquisition of assets (in shares)

'

45,713,000

'

'

'

'

'

'

'

'

'

'

Issued shares of common stock for acquisition of assets

342,734

456

'

342,278

'

'

'

'

'

'

'

'

Issued shares of Common Stock to employees for change in control payments for NGAS Resources (in shares)

'

351,000

'

'

'

'

'

'

'

'

'

'

Issued shares of Common Stock to employees for change in control payments for NGAS Resources

2,802

4

'

2,798

'

'

'

'

'

'

'

'

Issued 138,388 warrants in replacement of NGAS Resources warrants

190

'

'

190

'

'

'

'

'

'

'

'

Issued common units of Eureka Hunter Holdings for asset acquisition / Noncontrolling interest acquired in NGAS acqusition for the years ended December 31, 2012 and 2011, respectively

497

'

'

'

'

'

'

'

497

'

'

'

Issued exchangeable shares for acquisition of NuLoch Resources (in shares)

'

'

4,276,000

'

'

'

'

'

'

'

'

'

Issued exchangeable shares for acquisition of NuLoch Resources

31,643

'

43

31,600

'

'

'

'

'

'

'

'

Common stock issued upon exchange of MHR Exchangeco Corporation's exchangeable shares (in shares)

'

-582,000

-582,000

'

'

'

'

'

'

'

'

'

Issued shares of common stock upon exchange of MHR Exchangeco Corporation's exchangeable shares

0

6

-6

'

'

'

'

'

'

'

'

'

Purchase of outstanding non-controlling interest in a subsidiary

0

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

-76,412

'

'

'

-76,661

'

'

'

249

'

'

'

Other comprehensive income:

'

'

'

'

'

'

'

'

'

'

'

'

Foreign currency translation

-12,477

'

'

'

'

-12,477

'

'

'

'

'

'

Unrealized gain on available for sale securities

14

'

'

'

'

14

'

'

'

'

'

'

BALANCE at Dec. 31, 2011

490,652

1,298

37

569,690

-140,070

-12,463

-1,310

-604

2,196

'

71,878

0

BALANCE (in shares) at Dec. 31, 2011

'

129,803,000

3,694,000

'

'

'

'

'

'

'

1,438,000

0

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

Share based compensation (in shares)

'

108,000

'

'

'

'

'

'

'

'

'

'

Share based compensation

15,696

1

'

15,695

'

'

'

'

'

'

'

'

Issued shares as Employer Match on 401K (in shares)

'

199,000

'

'

'

'

'

'

'

'

'

'

Issued shares as Employer Match on 401K

874

2

'

872

'

'

'

'

'

'

'

'

Issued shares of stock for cash (in shares)

'

35,000,000

'

'

'

'

'

'

'

2,771,263

'

'

Issued shares of Common Stock for cash

148,241

350

'

147,891

'

'

'

'

'

'

'

'

Issued shares of Preferred Stock for Cash (in cash)

'

'

'

'

'

'

'

'

'

'

2,771,000

1,000

Issued shares of Preferred Stock for cash

144,635

'

'

-18,928

'

'

'

'

'

'

138,563

25,000

Issued shares of Common Stock upon exercise of warrants and options (in shares)

'

1,438,000

'

'

'

'

'

'

'

'

'

'

Issued shares of Common Stock upon exercise of warrants and options

2,331

14

'

2,317

'

'

'

'

'

'

'

'

Preferred dividends

-34,706

'

'

'

-34,706

'

'

'

'

'

'

'

Common stock returned to treasury and on Triad Acquisition for the years ended December 31, 2012 and 2010, respectively

0

'

'

'

'

'

-604

604

'

'

'

'

Issued shares of common stock for acquisition of assets (in shares)

'

297,000

'

'

'

'

'

'

'

'

'

'

Issued shares of common stock for acquisition of assets

1,902

3

'

1,899

'

'

'

'

'

'

'

'

Issued shares of Preferred Stock for acquisition of assets (in shares)

'

'

'

'

'

'

'

'

'

'

'

3,000

Issued shares of Preferred Stock for acquisition of assets

64,968

'

'

-4,403

'

'

'

'

'

'

'

69,371

Issued common units of Eureka Hunter Holdings for asset acquisition / Noncontrolling interest acquired in NGAS acqusition for the years ended December 31, 2012 and 2011, respectively

12,453

'

'

'

'

'

'

'

12,453

'

'

'

Common stock issued upon exchange of MHR Exchangeco Corporation's exchangeable shares (in shares)

'

-3,188,000

-3,188,000

'

'

'

'

'

'

'

'

'

Issued shares of common stock upon exchange of MHR Exchangeco Corporation's exchangeable shares

0

32

-32

'

'

'

'

'

'

'

'

'

Purchase of outstanding non-controlling interest in a subsidiary

-497

'

'

'

'

'

'

'

-497

'

'

'

Shares of Series E Preferred Stock received in reimbursement

-1,750

'

'

'

'

'

-1,750

'

'

'

'

'

Net income (loss)

-136,721

'

'

'

-132,708

'

'

'

-4,013

'

'

'

Other comprehensive income:

'

'

'

'

'

'

'

'

'

'

'

'

Foreign currency translation

3,883

'

'

'

'

3,883

'

'

'

'

'

'

Unrealized gain on available for sale securities

-309

'

'

'

'

-309

'

'

'

'

'

'

BALANCE at Dec. 31, 2012

711,652

1,700

5

715,033

-307,484

-8,889

-3,664

0

10,139

'

210,441

94,371

BALANCE (in shares) at Dec. 31, 2012

'

170,033,000

506,000

'

'

'

'

'

'

'

4,209,000

4,000

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

Share based compensation (in shares)

'

183,000

'

'

'

'

'

'

'

'

'

'

Share based compensation

13,624

2

'

13,622

'

'

'

'

'

'

'

'

Issued shares as Employer Match on 401K (in shares)

'

221,000

'

'

'

'

'

'

'

'

'

'

Issued shares as Employer Match on 401K

1,192

2

'

1,190

'

'

'

'

'

'

'

'

Issued shares of Preferred Stock for Cash (in cash)

'

'

'

'

'

'

'

'

'

'

216,000

0

Issued shares of Preferred Stock for cash

10,181

'

'

-1,320

'

'

'

'

'

'

10,803

698

Issued shares of Common Stock upon redemption of Series B Convertible Preferred Stock (in shares)

'

1,466,000

'

'

'

'

'

'

'

'

'

'

Issued shares of Common Stock upon redemption of Series B Convertible Preferred Stock

5,352

15

'

5,337

'

'

'

'

'

'

'

'

Preferred dividends

-56,705

'

'

'

-56,705

'

'

'

'

'

'

'

Common stock issued upon exchange of MHR Exchangeco Corporation's exchangeable shares (in shares)

'

-506,000

-506,000

'

'

'

'

'

'

'

'

'

Issued shares of common stock upon exchange of MHR Exchangeco Corporation's exchangeable shares

0

5

-5

'

'

'

'

'

'

'

'

'

Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs

-109

'

'

-109

'

'

'

'

'

'

'

'

Stockholders' Equity, Stock Returned from Escrow

-280

'

'

'

'

'

-280

'

'

'

'

'

Purchase of outstanding non-controlling interest in a subsidiary

0

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

-223,164

'

'

'

-222,176

'

'

'

-988

'

'

'

Other comprehensive income:

'

'

'

'

'

'

'

'

'

'

'

'

Foreign currency translation

-10,928

'

'

'

'

-10,928

'

'

'

'

'

'

Unrealized gain on available for sale securities

-84

'

'

'

'

-84

'

'

'

'

'

'

Other

-1

'

'

'

'

'

'

'

-1

'

'

'

BALANCE at Dec. 31, 2013

$450,730

$1,724

$0

$733,753

($586,365)

($19,901)

($3,944)

$0

$9,150

'

$221,244

$95,069

BALANCE (in shares) at Dec. 31, 2013

'

172,409,000

0

'

'

'

'

'

'

'

4,425,000

4,000

CONSOLIDATED_STATEMENT_OF_SHAR1

CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY (Parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2011
Statement of Stockholders' Equity [Abstract]	'
Warrants issued for payment of dividend	12,875,093
Warrants for payment of dividends on common stock, fair market value (in dollars)	$6,700,000
Warrants for payment of dividends on MHR Exchangeco Corporation	378,174
Warrants for payment of dividends on exchangeable shares, fair market value (in dollars)	$197,000
Warrants issued for replacement	138,388

CONSOLIDATED_STATEMENT_OF_CASH

CONSOLIDATED STATEMENT OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
NET LOSS	($223,164)	($136,721)	($76,412)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:	'	'	'
Depletion, depreciation, amortization and accretion	134,867	135,896	49,090
Share-based compensation	13,624	15,696	25,057
Impairment of oil and gas properties	89,041	4,096	21,782
Exploration	115,069	116,686	1,118
Gain on sale of assets	-7,318	-3,074	-186
Cash paid for plugging wells	-14	'	'
Loss (gain) on open derivative contracts	17,058	-10,945	4,210
Loss (gain) on investments	-7,009	2,200	0
Amortization and write off of deferred financing cost and discount on Senior Notes included in interest expense	4,836	7,399	3,636
Deferred tax benefit	-84,527	-21,595	-696
Changes in operating assets and liabilities:	'	'	'
Accounts receivable, net	22,781	-73,549	-25,075
Inventory	4,658	-6,198	-3,889
Prepaid expenses and other current assets	-1,073	-538	-124
Accounts payable	42,050	16,390	25,883
Revenue payable	-11,589	8,776	6,979
Accrued liabilities	2,421	3,492	2,465
Net cash provided by operating activities	111,711	58,011	33,838
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Change in restricted cash	-3,500	0	0
Capital expenditures and advances	-631,511	-568,610	-291,942
Cash paid in acquisitions, net of cash received of $0; $34; and $2,500, respectively	0	-444,844	-78,524
Proceeds from sale of assets	506,297	4,158	8,709
Change in deposits and other long-term assets	854	89	42
Net cash used in investing activities	-127,860	-1,009,207	-361,715
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Proceeds from issuing Senior Notes	0	596,907	0
Proceeds from borrowings on debt	373,991	546,043	493,906
Principal repayments of debt	-380,923	-542,654	-242,472
Proceeds from sale of Series A preferred units in Eureka Hunter Holdings	35,280	149,655	0
Net proceeds from sale of common stock	0	148,241	13,892
Net proceeds from sale of preferred shares	10,072	144,635	94,764
Proceeds from exercise of warrants and options	5,352	2,331	7,618
Change in other long-term liabilities	-1,222	186	69
Purchase of treasury shares	0	-1,750	0
Payment of deferred financing costs	-1,246	-20,313	-11,577
Preferred stock dividends paid	-40,648	-26,839	-14,007
Net cash provided by financing activities	656	996,442	342,193
Effect of foreign exchange rate changes on cash	-417	-2,474	-19
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-15,910	42,772	14,297
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	57,623	14,851	554
CASH AND CASH EQUIVALENTS, END OF YEAR	$41,713	$57,623	$14,851

CONSOLIDATED_STATEMENT_OF_CASH1

CONSOLIDATED STATEMENT OF CASH FLOWS (Parenthetical) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Cash Flows [Abstract]	'	'	'
Cash Acquired from Acquisition	$0	$34	$2,500

ORGANIZATION_NATURE_OF_OPERATI

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	NOTE 1 - ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Magnum Hunter Resources Corporation, a Delaware corporation, operating directly and indirectly through its subsidiaries (“Magnum Hunter” or the “Company”), is a Houston, Texas based independent exploration and production company engaged in the acquisition and development of producing properties and undeveloped acreage and the production of oil and natural gas in the United States and Canada, along with certain midstream and oil field service activities.
	Presentation of Consolidated Financial Statements
	The consolidated financial statements include the accounts of the Company and entities in which it holds a controlling interest. Our financial statements are prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). All significant intercompany balances and transactions have been eliminated. The preparation of our financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses. These estimates are based on information that is currently available to us and on various other assumptions that it believes to be reasonable under the circumstances. Actual results could differ from those estimates under different assumptions and conditions. Significant estimates are required for proved oil and gas reserves which may have a material impact on the carrying value of oil and gas property, and of assets held for sale.
	Non-Controlling Interest in Consolidated Subsidiaries
	The Company has consolidated Eureka Hunter Holdings, LLC (“Eureka Hunter Holdings”) in which it owns 56.4% and 61.0% as of December 31, 2013 and 2012, respectively. Eureka Hunter Holdings owns, directly or indirectly, 100% of the equity interests of Eureka Hunter Pipeline, LLC ("Eureka Hunter Pipeline"), TransTex Hunter, LLC and Eureka Hunter Land, LLC. On December 30, 2013, the Company’s subsidiary, PRC Williston, LLC ("PRC Williston"), in which the Company owned 87.5%, sold substantially all of its assets. The consolidated financial statements also reflect the interests of Magnum Hunter Production, Inc. (MHP) in various managed drilling partnerships. The Company accounts for the interests in these partnerships using the proportionate consolidation method.
	Divestitures and Discontinued Operations
	As a result of the sale of Hunter Disposal, LLC in 2012, the Company reclassified the assets and liabilities of this entity to assets and liabilities held for sale and the gain on sale and all prior operating income and expense for this entity as discontinued operations. On April 24, 2013, the Company sold all of its ownership interest in its 100%-owned subsidiary, Eagle Ford Hunter, Inc. ("Eagle Ford Hunter"). In September 2013, the Company adopted a plan to divest all of its interests in (i) MHP, a 100%-owned subsidiary of the Company whose oil and natural gas operations are located primarily in the southern Appalachian Basin in Kentucky and Tennessee, and (ii) the Canadian operations of Williston Hunter Canada, Inc., a 100%-owned subsidiary of the Company ("WHI Canada"). The Company has reflected the operations of Eagle Ford Hunter and MHP, which have historically been included as part of the U.S. Upstream operating segment and WHI Canada, which historically has been the only member of our Canadian Upstream segment, as discontinued operations for all periods presented. See "Note 2 - Divestitures and Discontinued Operations".
	Reclassification of Prior-Year Balances
	Certain prior-year balances in the consolidated financial statements have been reclassified to correspond with current-year classifications.
	Cash and cash equivalents
	Cash and cash equivalents include cash in banks and highly liquid debt securities that have original maturities of three months or less. At December 31, 2013, the Company had cash deposits in excess of FDIC insured limits at various financial institutions.
	Financial Instruments
	The carrying amounts of financial instruments including cash and cash equivalents, accounts receivable, notes receivable, accounts payable and accrued liabilities, derivatives, and certain long-term debt approximate fair value as of December 31, 2013 and 2012. See "Note 3 - Fair Value of Financial Instruments".
	Inventory
	The Company’s materials and supplies inventory is primarily comprised of frac sand used in the completion process of hydraulic fracturing. Frac sand is acquired for use in future well completion operations or repair operations and is carried at the lower of cost or market, on a first-in, first-out cost basis. “Market,” in the context of inventory valuation, represents net realizable value, which is the amount that the Company is allowed to bill to the joint accounts under joint operating agreements to which the Company is a party. Valuation reserve allowances for materials and supplies inventories are recorded as reductions to the carrying values of the materials and supply inventories in the Company’s consolidated balance sheets and as operating expense in the accompanying consolidated statements of operations. As of December 31, 2012 , the Company estimated that $3.5 million of its frac sand inventory would not be utilized within one year. Accordingly, those inventory values were classified as other long term assets in the accompanying consolidated balance sheet as of December 31, 2012. As of December 31, 2013 the frac sand inventory is anticipated to be entirely used within the coming year, and all inventories are classified as current.
	Commodities inventories are carried at the lower of average cost or market, on a first-in, first-out basis. The Company’s commodities inventories consist of crude oil held in storage and is carried at the lower of average cost or market, on a first in, first out basis. Any valuation allowances of commodities inventories are recorded as reductions to the carrying values of the commodities inventories included in the Company’s consolidated balance sheets and as charges to lease operating expense in the consolidated statements of operations.
	The following table sets forth the Company's inventory as of December 31, 2013 and December 31, 2012, respectively:
		2013				2012
		(in thousands)
	Materials and supplies	$	6,790			$	11,531
	Commodities	368				1,095
	Less:
	Materials included in other long term assets	—				(3,464		)
	Inventory	$	7,158			$	9,162
	Oil and Natural Gas Properties
	Capitalized Costs
	Our oil and natural gas properties comprised the following:
		December 31,
		2013				2012
		(in thousands)
	Mineral interests in properties:
	Unproved leasehold costs	$	469,337			$	645,164
	Proved leasehold costs	336,357				454,556
	Wells and related equipment and facilities	438,275				727,711
	Uncompleted wells, equipment and facilities	97,748				71,665
	Advances to operators for wells in progress	13,571				9,563
	Total costs	1,355,288				1,908,659
	Less accumulated depreciation, depletion, and amortization	(130,629		)		(186,156		)
	Net capitalized costs	$	1,224,659			$	1,722,503
	The Company follows the successful efforts method of accounting for oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties and to drill and equip new development wells and related asset retirement costs are capitalized. Costs to acquire mineral interests and drill exploratory wells are also capitalized pending determination of whether the wells have proved reserves or not. If the Company determines that the wells do not have proved reserves, the costs are charged to exploration expense. Geological and geophysical costs, including seismic studies and related costs of carrying and retaining unproved properties are charged to exploration expense as incurred.
	On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depreciation, depletion, and amortization are eliminated from the property accounts, and the resultant gain or loss is recognized. On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated depreciation, depletion, and amortization with no resulting gain or loss recognized in income. A sale of an entire field is generally treated as discontinued operations.
	Leasehold costs attributable to proved oil and gas properties are depleted by the unit-of-production method over total proved reserves. Capitalized development costs are depleted by the unit-of-production method over producing proved reserves. Depreciation, depletion, amortization and accretion expense for oil and gas producing property and related equipment was $69.0 million, $49.2 million, and $18.4 million for the years ended December 31, 2013, 2012, and 2011, respectively.
	Unproved oil and gas leasehold costs that are individually significant are periodically assessed for impairment of value by comparing current quotes and recent acquisitions, and taking into account management's intent, and a loss is recognized at the time of impairment by providing an impairment allowance in exploration expense.
	Capitalized costs related to proved oil and gas properties, including wells and related equipment and facilities, are evaluated for impairment quarterly based on an analysis of undiscounted future net cash flows. If undiscounted future net cash flows are insufficient to recover the net capitalized costs related to proved properties, then the Company recognizes an impairment charge in income from operations equal to the difference between the net capitalized costs related to proved properties and their estimated fair values based on the present value of the related future net cash flows and other relevant market value data. Impairment of proved oil and gas properties is calculated on a field by field basis.
	It is common for operators of oil and gas properties to request that joint interest owners pay for large expenditures, typically for drilling new wells, in advance of the work commencing. This right to call for cash advances is typically a provision of the joint operating agreement that working interest owners in a property adopt. The Company records these advance payments to Advances in the property accounts and reclassifies amounts from this account when the actual expenditure is later billed to us by the operator.
	If an unproved property is sold or the lease expires without identifying proved reserves, the cost of the property is charged to the impairment allowance. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.
	Estimates of Proved Oil and Natural Gas Reserves
	Estimates of our proved reserves included in this report are prepared in accordance with U.S. SEC guidelines for reporting corporate reserves and future net revenue. The accuracy of a reserve estimate is a function of:
	·      the quality and quantity of available data;
	·      the interpretation of that data;
	·      the accuracy of various mandated economic assumptions; and
	·      the judgment of the persons preparing the estimate.
	Our proved reserve information included in this report was predominately based on evaluations reviewed by independent third party petroleum engineers. Estimates prepared by other third parties may be higher or lower than those included herein. Because these estimates depend on many assumptions, all of which may substantially differ from future actual results, reserve estimates will be different from the quantities of oil and gas that are ultimately recovered. In addition, results of drilling, testing and production after the date of an estimate may justify material revisions to the estimate.
	In accordance with SEC requirements, the Company based the estimated discounted future net cash flows from proved reserves on the unweighted arithmetic average of the  prior 12-month commodity prices as of the first day of each of the months constituting the period and costs on the date of the estimate.
	The estimates of proved reserves materially impact depreciation, depletion, amortization and accretion (DDA&A) expense. If the estimates of proved reserves decline, the rate at which the Company records DDA&A expense will increase, reducing future net income. Such a decline may result from lower market prices, which may make it uneconomic to drill for and produce from higher-cost fields.
	Oil and Natural Gas Operations
	Revenue Recognition
	Revenues associated with sales of crude oil, natural gas, and natural gas liquids are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry.
	Revenues from the production of natural gas and crude oil from properties in which the Company has an interest with other producers are recognized based on the actual volumes sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be non-recoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropriate. Cumulative differences between volumes sold and entitlement volumes are generally not significant.
	During the years ended December 31, 2013, 2012, and 2011 the Company recognized sales of oil, natural gas and NGL as follows:
		Year Ended December 31,
		2013				2012			2011
					(in thousands)
Oil	$	140,426			$	77,172		$	37,520
Natural gas	41,867				36,657			21,206
NGL	15,306				830			—
Total oil and natural gas sales	$	197,599			$	114,659		$	58,726
Revenues from field servicing activities are recognized at the time the services are provided and earned as provided in the various contract agreements. Gas gathering revenues are recognized at the time the natural gas is delivered at the destination point.
Accounts Receivable
The Company recognizes revenue for our production when the quantities are delivered to or collected by the respective purchaser. Prices for such production are defined in sales contracts and are readily determinable or estimable based on available data.
Accounts receivable from joint interest owners consist of joint interest owner obligations due within 30 days of the invoice date. Accounts receivable, oil and gas sales, consist of accrued revenues due under normal trade terms, generally requiring payment within 30 to 60 days of production. The Company reviews accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. As of December 31, 2013 and 2012, the Company had allowances for doubtful accounts of $0.3 million and $0.4 million respectively.
Revenue Payable
Revenue payable represents amounts collected from purchasers for oil and gas sales which are either revenues due to other working or royalty interest owners or severance taxes due to the respective state or local tax authorities. Generally, the Company is required to remit amounts due under these liabilities within 30 days of the end of the month in which the related production occurred.
Lease Operating Expenses
Lease operating expenses, including compressor rental and repair, pumpers’ salaries, saltwater disposal, ad valorem taxes, insurance, repairs and maintenance, workovers and other operating expenses are expensed as incurred. Transportation, gathering, and processing costs are expensed as incurred and included in lease operating expenses.
Exploration
Exploration expense consists primarily of impairment reserves for abandonment costs associated with unproved properties for which the Company has no further exploration or development plans, exploratory dry hole costs, and geological and geophysical costs. The following table provides the Company's exploration expense for 2013, 2012 and 2011:
	Year Ended December 31,
	2013				2012			2011
	(in thousands)
Geological and geophysical	$	1,402			$	2,570		$	1,497
Leasehold impairments:
Williston Basin	89,167				59,214			—
Appalachian Basin	6,773				15,033			802
South Texas	—				1,404			306
	$	97,342			$	78,221		$	2,605
The Company's exploration expense was primarily attributable to leasehold impairments, due to the large acreage position the Company initially acquired and results to date in the area, which led us to focus on other areas, thereby letting certain acreage expire in that region. The Company did not drill any dry holes in 2013, 2012, or 2011.
Impairment of Proved Oil and Natural Gas Properties
During the years ended December 31, 2013, 2012 and 2011, the Company recorded proved property impairments as follows:
	Year Ended December 31,
	2013				2012			2011
	(in thousands)
Williston Basin	$	8,498			$	3,631		$	—
Appalachian Basin	1,151				76			—
South Texas	319				65			—
	$	9,968			$	3,772		$	—
Severance Taxes and Marketing Costs
Severance taxes are comprised of production taxes charged by most states on oil, natural gas, and natural gas liquids produced. These taxes are computed on the basis of volumes and/or value of production or sales. These taxes are usually levied at the time and place the minerals are severed from the producing reservoir. Marketing costs are those directly associated with marketing our production and are based on volumes.
Gas Gathering and Processing Costs
Gas gathering and processing costs are those costs associated with oil and gas gathering revenues of our midstream operations.
Dependence on Major Customers
The Company's share of oil and gas production is sold to various purchasers who must be prequalified under the Company's credit risk policies and procedures. The Company records allowances for doubtful accounts based on the age of accounts receivables and the financial condition of its purchasers and, depending on facts and circumstances, may require purchasers to provide collateral or otherwise secure their accounts. The loss of any one significant purchaser could have a material, adverse effect on the ability of the Company to sell its oil and gas production in a certain region. Although the Company is exposed to a concentration of credit risk, it believes that all of its purchasers are credit worthy. See "Note 13 - Major Customers".
Dependence on Suppliers
Our industry is cyclical, and from time to time there is a shortage of drilling rigs, fracture stimulation services, equipment, related supplies and qualified personnel. During these periods, the costs and delivery times of rigs, equipment and supplies are substantially greater. If the unavailability or high cost of drilling rigs, equipment, supplies or qualified personnel were particularly severe in the areas where the Company operates, it could be materially and adversely affected. The Company believes that there are potential alternative providers of drilling services and that it may be necessary to establish relationships with new contractors as our activity level increases and capital program grows. However, there can be no assurance that the Company can establish such relationships and that those relationships will result in increased availability of drilling rigs.
Gas Transportation, Gathering and Processing Equipment and Other
Our gas gathering system assets and field servicing assets are carried at cost. The Company capitalizes interest on expenditures for significant construction projects that last more than six months while activities are in progress to bring the assets to their intended use. Interest of $2.6 million and $4.4 million was capitalized on our Eureka Hunter Gas Gathering System during the years ended 2013 and 2012, respectively. The Company did not capitalize any interest in 2011. Depreciation of gas gathering system assets is provided using the straight line method over an estimated useful life of fifteen years. Depreciation of field servicing assets is provided using the straight line method over various useful lives ranging from three to ten years. Gain or loss on retirement or sale or other disposition of assets is included in income in the period of disposition.
Furniture, fixtures and equipment are carried at cost. Depreciation of furniture, fixtures and equipment is provided using the straight-line method over estimated useful lives ranging from five to fifteen years. Gain or loss on retirement or sale or other disposition of assets is included in other income in the period of disposition.
Such equipment is comprised of the following:
	December 31,
	2013				2012
	(in thousands)
Gas transportation, gathering and processing equipment and other	$	315,642			$	218,656
Less accumulated depreciation and depletion	(26,222		)		(16,746		)
Net capitalized costs	$	289,420			$	201,910
Depreciation expense for other property and equipment was $15.6 million, $8.1 million, and $7.8 million, for the years ended December 31, 2013, 2012, and 2011, respectively.
TransTex Hunter sells and leases gas treating and processing equipment, much of which is leased to third party operators for treating gas at the wellhead. The leases generally have a term of three years or less. The equipment under leases in place as of December 31, 2013 had terms for future payments extending as far as December 2016. TransTex Hunter has non-cancelable leases to third parties in place as of December 31, 2013, with future minimum base rentals of $4.4 million, and $0.9 million, and $0.2 million for the years ending December 31, 2014, 2015, and 2016, respectively. Equipment leasing revenue is reported in gas transportation, gathering, and processing revenue in our statement of operations.
Deferred Financing Costs
In connection with debt financings, the Company paid $1.2 million and $20.3 million in fees in the year ended December 31, 2013, and 2012, respectively. These fees were recorded as deferred financing costs and are being amortized over the life of the debt instrument using the straight line method for debt in the form of a line of credit and effective interest method for term loans. Amortization and write off of deferred financing costs for the years ended December 31, 2013, 2012, and 2011 was $4.8 million, $7.1 million, and $3.6 million, respectively.
Commodity and Financial Derivative Instruments
The Company uses commodity and financial derivative instruments, typically options and swaps, to manage the risk associated with fluctuations in oil and gas prices, and the Company accounts for these instruments in accordance with ASC 815 - Derivatives and Hedging. The Company also has an embedded derivative liability resulting from certain conversion features, redemption options, and other features of our Series A Convertible Preferred Units of Eureka Hunter Holdings, LLC and an embedded derivative asset resulting from the bifurcated conversion feature associated with the convertible note received as partial consideration upon the sale of Hunter Disposal, LLC. See "Note 3 - Fair Value of Financial Instruments", "Note 2 - Divestitures and Discontinued Operations", "Note 10 - Shareholders' Equity", and "Note 16 - Related Party Transactions".
Derivative instruments are recorded at fair value in the balance sheet as either an asset or liability, with those contracts maturing in the next twelve months classified as current, and those maturing thereafter as long-term. The Company recognizes changes in the derivatives' fair values in earnings, as it has not designated our oil and gas price derivative contracts as cash flow hedges. The Company recognizes the gains and losses on settled and open transactions on a net basis within the “Gain (loss) on derivative contracts” line item within the “Other Income (expense)” section of the Consolidated Statement of Operations.
Investments
Investments are comprised of common and preferred stock of companies publicly traded on the TSX Venture Exchange and the NYSE MKT (formerly NYSE Amex) with quoted prices in active markets. On February 17, 2012, the Company received 1,846,722 restricted common shares of GreenHunter Resources, Inc., which has a carrying value of $0.6 million and $1.3 million at December 31, 2013 and 2012, respectively, and 88,000 shares of GreenHunter Resources, Inc. 10% Series C Preferred Stock, which has a fair value of $1.7 million and $1.7 million at December 31, 2013 and 2012, respectively, as partial consideration for the sale by our wholly-owned subsidiary, Triad Hunter, LLC, of its equity ownership interest in Hunter Disposal, LLC to GreenHunter Resources, Inc. The GreenHunter common stock investment is accounted for under the equity method within the scope of ASC 323: Investments - Equity Method. The Company initially accounted for its investment in GreenHunter’s Series C Preferred Stock under the cost method specified in ASC 325: Investments - Other. The preferred shares were cost basis investments from February 17, 2012 through July 31, 2012, since the preferred stock was not publicly traded and did not have a readily determinable fair value, and therefore ineligible for accounting under ASC 320: Investments - Debt and Equity Securities.
Beginning July 31, 2012, the GreenHunter Series C Preferred Stock is publicly traded with a readily determinable fair value and is classified as available for sale within the scope of ASC 320. Available-for-sale assets are securities and other financial investments that are neither held for trading, nor held to maturity, nor held for strategic reasons, and that have a readily available market price. As such, the gains and losses resulting from marking available-for-sale investments to market are not included in net income but are reflected in other comprehensive income until they are realized.
Below is a summary of changes in investments for the years ended December 31, 2013 and 2012:
	Available for Sale Securities (1)				Equity Method Investments (2)			Cost Method Investments
	(in thousands)
Fair value at December 31, 2011	$	497			$	—		$	—
Additional cost basis from acquisition	—				3,943			1,870
Transfers	1,770				—			(1,770		)
Decrease in carrying amount return of capital	—				—			(100		)
Equity in net loss recognized in other income (expense)	—				(1,333		)	—
Impairment in carrying value of equity method investment recognized in other income (expense)	—				(538		)	—
Change in fair value recognized in other comprehensive loss	(309		)		—			—
Fair value at December 31, 2012	$	1,958			$	2,072		$	—
Securities received as consideration	42,300				—			—
Sales of securities	(50,562		)		—			—
Realized gain recognized in net income	8,262				—			—
Decrease in carrying amount return of capital	—				(138		)	—
Equity in net loss recognized in other income (expense)	—				(767		)	—
Impairment in carrying value of equity method investment recognized in other income (expense)	—				(227		)	—
Other adjustments	(55		)		—
Change in fair value recognized in other comprehensive loss	(84		)		—			—
Fair value as of December 31, 2013	$	1,819			$	940		$	—
(1) Available for sale securities above includes $147,000 that has been classified as held for sale associated with the classification of the MHP subsidiary.
(2) Equity method investments includes $350,000 classified as long term other assets.
On April 24, 2013, the Company received 10.0 million shares of common stock of Penn Virginia Corporation valued at approximately $42.3 million as partial consideration for the sale of our wholly-owned subsidiary, Eagle Ford Hunter. As of September 30, 2013, the Company had sold all of the shares of Penn Virginia common stock, for total gross proceeds of approximately $50.6 million in cash, recognizing a gain of $8.3 million in other income.
Goodwill and Other Intangible Assets
During 2012, the Company recorded goodwill associated with the acquisition of the assets of TransTex Gas Services, LP, which represents the fair value of the acquired entity over the net amounts assigned to assets acquired and liabilities assumed. In accordance with GAAP, goodwill is not amortized to earnings, but is assessed annually in April for impairment, or whenever events or circumstances indicate that impairment of the carrying value of goodwill is likely. The Company has established April 1 as the annual testing date. If the carrying value of goodwill is determined to be impaired, it is reduced to its implied fair value with a corresponding charge to pretax earnings in the period in which it is determined to be impaired. Financial Accounting Standards Board ("FASB") Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350) permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. The Company used this approach, and performed a full qualitative analysis of the need for impairment as of April 1, 2013. The Company performed a follow up analysis to determine if there were any triggering events as of December 31, 2013, and if an interim analysis was necessary, and none were determined to exist, as TransTex Gas Services, LP has experienced positive results on the Company's performance measures, and it has not experienced any significant adverse conditions.
Intangible assets consist primarily of the fair value of the acquired gas treating agreements and customer relationships in the TransTex Gas Services, LP assets acquisition.  The intangible assets were valued at fair value using a discounted cash flow model with a discount rate at the date of acquisition of 13%.  Such assets are being amortized over the weighted average term of 8.5 years.  The customer relationships are being amortized with a 12.5 year life. The Company assesses the carrying amount of its other intangible assets for impairment when events or changes in circumstances indicate the carrying value may not be recoverable. At December 31, 2013, our other intangible assets were not impaired. See "Note 6 - Goodwill and Intangible Assets ".
Assets Held for Sale
Assets held for sale as of December 31, 2013 relate to the Company's interests in (i) Magnum Hunter Production, Inc. (“MHP”), a wholly-owned subsidiary of the Company whose oil and natural gas operations are located primarily in the southern Appalachian Basin in Kentucky and Tennessee, and (ii) the Canadian operations of Williston Hunter Canada, Inc., a wholly-owned subsidiary of the Company ("WHI Canada"). The Company is actively marketing these interests and anticipates completing the divestitures by the second quarter of 2014. Assets for sale as of December 31, 2012 relate to a drilling rig owned by Alpha Hunter Drilling, a subsidiary of Triad Hunter, LLC. The following table summarizes assets held for sale for the years indicated. See "Note 2 - Divestitures and Discontinued Operations.”
	December 31,
	2013				2012
	(in thousands)
MHP
Current portion	$	3,495			$	—
Long term portion	99,616				—
Total MHP assets held for sale	$	103,111			$	—
WHC
Current portion	$	1,871			$	—
Long term portion	63,071				—
Total WHC assets held for sale	$	64,942			$	—
Alpha Hunter Drilling
Current portion	$	—			$	500
Long-term portion	—				—
Total Alpha Hunter Drilling assets held for sale	$	—			$	500
Asset Retirement Obligation
The asset retirement obligation ("ARO") primarily represents the estimated present value of the amount the Company will incur to plug, abandon and remediate our producing properties at the projected end of their productive lives, in accordance with applicable federal, state and local laws. The Company determined its ARO by calculating the present value of estimated cash flows related to the obligation. The retirement obligation is recorded as a liability at its estimated present value as of the asset’s inception, with an offsetting increase to proved properties. Periodic accretion of discount of the estimated liability is recorded as accretion expense in the consolidated statements of operations.
The liability is determined using significant assumptions, including current estimates of plugging and abandonment costs, annual inflation of these costs, the productive lives of wells and our risk-adjusted interest rate. Changes in any of these assumptions can result in significant revisions to the estimated ARO. The liability for current and long term AROs were approximately $0.1 million and $16.2 million, respectively, at December 31, 2013, and $2.4 million and $28.3 million, respectively, at December 31, 2012. The liability for current AROs is reported in other current liabilities. See "Note 7 - Asset Retirement Obligations".
Share-Based Compensation
The Company estimates the fair value of share-based payment awards made to employees and directors, including stock options, restricted stock and matching contributions of stock to employees under our employee stock ownership plan, on the date of grant using an option-pricing model. The value of the portion of the award that is ultimately expected to vest is recognized as an expense ratably over the requisite service periods. Awards that vest only upon achievement of performance criteria are recorded only when achievement of the performance criteria is considered probable. The Company estimated the fair value of each share-based award using the Black-Scholes option pricing model or a lattice model. These models are highly complex and dependent on key estimates by management. The estimates with the greatest degree of subjective judgment are the estimated lives of the stock-based awards, the estimated volatility of our stock price, and the assessment of whether the achievement of performance criteria is probable.
Income Taxes
Income taxes are accounted for in accordance with FASB ASC 740, under which deferred income taxes are recognized for the future tax effects of temporary differences between the financial statement carrying amounts and the tax basis of existing assets and liabilities using the enacted statutory tax rates in effect at year-end. The effect on deferred taxes for a change in tax rates is recognized in earnings in the period that includes the enactment date. A valuation allowance for deferred tax assets is recorded when it is more likely than not that the benefit from the deferred tax asset will not be realized.
Uncertain Income Tax Positions
Under accounting standards for uncertainty in income taxes (ASC 740-10), a company recognizes a tax benefit in the financial statements for an uncertain tax position only if management's assessment is that the position is “more likely than not” (i.e., a likelihood greater than 50 percent) to be allowed by the tax jurisdiction based solely on the technical merits of the position. The term “tax position” in the accounting standards for income taxes refers to a position in a previously filed tax return or a position expected to be taken in a future tax return that is reflected in measuring current or deferred income tax assets and liabilities for interim or annual periods. The Company had no uncertain tax positions at December 31, 2013 or 2012.
Loss per Common Share
Basic net income or loss per common share is computed by dividing the net income or loss attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period. Diluted net income or loss per common share is calculated in the same manner, but also considers the impact to net income and common shares for the potential dilution from stock options, stock warrants and any outstanding convertible securities.
The Company has issued potentially dilutive instruments in the form of our restricted common stock granted and not yet issued, common stock warrants, common stock options granted to our employees and directors, and our Series E Cumulative Convertible Preferred Stock. The Company did not include any of these instruments in its calculation of diluted loss per share during the periods because to include them would be anti-dilutive due to the Company's loss from continuing operations during the periods.
The following table summarizes the types of potentially dilutive securities outstanding as of December 31, 2013, 2012 and 2011:
	December 31,
	2013			2012			2011
	(in thousands of shares)
Series E Preferred Stock	10,946			10,897			—
Warrants	17,169			13,376			13,526
Restricted shares granted, not yet issued	28			—			38
Common stock options	16,891			14,847			12,566
Total	45,034			39,120			26,130
Regulated Activities
Energy Hunter Securities, Inc. is a 100%-owned subsidiary and is a registered broker-dealer and member of the Financial Industry Regulatory Authority. Among other regulatory requirements, it is subject to the net capital provisions of Rule 15c3-1 under the Securities Exchange Act of 1934, as amended. Because it does not hold customer funds or securities or owe money or securities to customers, Energy Hunter Securities, Inc. is required to maintain minimum net capital equal to the greater of $5,000 or 6.67% of its aggregate indebtedness. At December 31, 2013 and 2012, Energy Hunter Securities, Inc. had net capital of $77,953 and $71,928, respectively, and aggregate indebtedness of $16,657 and $291,307, respectively.
Sentra Corporation, a 100%-owned subsidiary, owns and operates distribution systems for retail sales of natural gas in south central Kentucky. Sentra Corporation’s gas distribution billing rates are regulated by Kentucky’s Public Service Commission based on recovery of purchased gas costs. The Company accounts for its operations based on the provisions of ASC 980-605, Regulated Operations–Revenue Recognition, which requires covered entities to record regulatory assets and liabilities resulting from actions of regulators. For the years ended December 31, 2013, 2012, and 2011, the Company had gas transmission, compression and processing revenue, reported in other revenue, which included gas utility sales from Sentra Corporation’s regulated operations aggregating $216,000, $511,000, and $61,000, respectively.
Other Comprehensive Income (Loss)
The functional currency of the Company's operations in Canada (which operations are reflected in these financial statements as discontinued operations) is the Canadian dollar. For purposes of consolidation, the Company translates the assets and liabilities of its Canadian subsidiary into U.S. dollars at current exchange rates while revenues and expenses are translated at the average rates in effect for the period. The related translation gains and losses are included in accumulated other comprehensive income. During the year ended December 31, 2013, 2012, and 2011 the Company recognized a translation loss of $10.9 million, a gain of $3.9 million, and a loss of $12.5 million, respectively.
Unrealized gains and losses on changes in fair value of common and preferred stock of publicly traded companies are included in accumulated other comprehensive income. As of September 30, 2013, the Company had completed the sale of all of the shares of the Penn Virginia common stock it acquired in connection with its sale of Eagle Ford Hunter in April 2013. The Company received gross proceeds of $50.6 million, resulting in a reclassification out of comprehensive income of $8.3 million, which is classified within other income.

DIVESTITURES_AND_DISCONTINUED_

DIVESTITURES AND DISCONTINUED OPERATIONS	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
DIVESTITURES AND DISCONTINUED OPERATIONS	'
	NOTE 2 - DIVESTITURES AND DISCONTINUED OPERATIONS
	Discontinued Operations
	Sale of Hunter Disposal
	On February 17, 2012, the Company, through its 100%-owned subsidiary, Triad Hunter, LLC, sold 100% of its equity ownership interest in Hunter Disposal, LLC, to a 100%-owned subsidiary of GreenHunter Resources, Inc., for total consideration of $9.3 million, comprised of cash of $2.2 million, 1,846,722 restricted common shares of GreenHunter Resources, Inc., valued at $2.6 million based on a closing price of $1.79 per share, discounted for restrictions, 88,000 shares of GreenHunter Resources, Inc. 10% Series C Preferred Stock, with a fair value of $1.9 million, and a promissory note of $2.2 million which is convertible, at the option of the Company, into 880,000 shares of GreenHunter Resources, Inc. common stock based on the conversion price of $2.50 per share. The Company recognized an embedded derivative asset resulting from the conversion option on the convertible promissory note with an initial fair value of $405,000. See "Note 3 - Fair Value of Financial Instruments". The cash proceeds from the sale were adjusted downward to $783,000 for changes in working capital and certain fees to reflect the effective date of the sale of December 31, 2011. Triad Hunter recognized a gain on the sale of discontinued operations of $3.7 million, $2.4 million net of tax of $1.3 million. GreenHunter Resources, Inc. is a related party as described in "Note 16 - Related Party Transactions".
	Sale of Eagle Ford Hunter
	On April 24, 2013, the Company closed on the sale of all of its ownership interest in its wholly-owned subsidiary, Eagle Ford Hunter to an affiliate of Penn Virginia for a total purchase price of approximately $422.1 million paid to the Company in the form of $379.8 million in cash (after estimated customary initial purchase price adjustments) and 10.0 million shares of common stock of Penn Virginia valued at approximately $42.3 million (based on the closing market price of the stock of $4.23 as of April 24, 2013). The effective date of the sale was January 1, 2013. Upon closing of the sale, $325.0 million of sale proceeds were used to pay down outstanding borrowings under the MHR Senior Revolving Credit Facility. During the third quarter of 2013, the Company had completed the sale of all of its Penn Virginia common stock for gross proceeds of $50.6 million, recognizing a gain of $8.3 million in other income. Initially, the Company has recognized a gain on the sale of $172.5 million, net of tax.
	On August 24, 2013, the Company presented Penn Virginia with the Company’s estimate of the final settlement of the adjustments to the cash portion of the purchase price, to which Penn Virginia responded on October 21, 2013 with its calculation of the final adjustment amounts. On February 3, 2014, the Company submitted its updated calculation of the final adjustment amount to the arbitrator in the amount of $26.6 million (on a pre-tax basis) and Penn Virginia submitted its updated calculation of the final adjustment amount in the amount of $56.4 million. The Company is currently in the process of reviewing Penn Virginia’s calculation of the final adjustment amounts. As of December 31, 2013, the Company estimated that the final settlement of the adjustment amounts may result in an obligation to Penn Virginia ranging from $22 million to $33 million, net of taxes, but such estimate is subject to further review by the Company and discussions with Penn Virginia.  Therefore, the Company has recorded a liability for its revised estimate of the final settlement of the adjustment amounts, after taxes, as a reduction in the gain on disposal of discontinued operations of Eagle Ford Hunter.
	Planned Divestitures of Magnum Hunter Production and Williston Hunter Canada
	In September 2013, the Company adopted a plan to divest all of its interests in (i) Magnum Hunter Production, Inc. (“MHP”), a wholly-owned subsidiary of the Company whose oil and natural gas operations are located primarily in the southern Appalachian Basin in Kentucky and Tennessee, and (ii) the Canadian operations of Williston Hunter Canada, Inc., a wholly-owned subsidiary of the Company ("WHI Canada"). The Company is actively marketing these interests and anticipates completing the divestitures by the second quarter of 2014. The Company has reclassified the associated assets and liabilities to assets and liabilities held for sale and the operations are reflected as discontinued operations for all periods presented. The Company has recorded an impairment expense of $56.7 million , net of tax, for the year ended December 31, 2013 relating to the discontinued operations which is recorded in income (loss) from discontinued operations and an expense of $92.4 million, net of tax, to reflect the net assets at their estimated selling prices, less costs to sell, which is recorded in loss on disposal of discontinued operations for the year ended December 31, 2013.
	The Company included the results of operations of MHP and WHI Canada for all periods presented, Eagle Ford Hunter through April 24, 2013, and Hunter Disposal through February 17, 2012 in discontinued operations as follows:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Revenues	$	91,364		$	133,643		$	60,633
	Expenses (1)	(174,049		)	(160,127		)	(79,431		)
	Other income (expense)	6,847			3,431			1,366
	Income (loss) from discontinued operations before tax	(75,838		)	(23,053		)	(17,432		)
	Income tax benefit (expense) (2)	4,707			3,579			(2,166		)
	Income (loss) from discontinued operations, net of tax	(71,131		)	(19,474		)	(19,598		)
	Gain on disposal of discontinued operations, net of taxes (3)(4)	52,019			2,409			—
	Loss from discontinued operations, net of tax	$	(19,112	)	$	(17,065	)	$	(19,598	)
	_____________________
	-1	Includes impairment expense of $78.5 million, $324,000, and none for the years ended December 31, 2013, 2012, and 2011, respectively, and exploration expense of $19.6 million, $38.7 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively relating to the discontinued operations of MHP and WHI Canada, which is recorded in income (loss) from discontinued operations.
	-2	The Company’s effective tax rate on the loss from discontinued operations is 6.2% primarily due to the significant losses generated in WHI Canada, which has an overall lower statutory tax rate further lowered by the utilization of certain net operating losses.
	-3	Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.
	-4	The Company’s effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.
	Other Divestitures
	Sale of Certain North Dakota Oil and Natural Gas Properties
	On September 2, 2013, Williston Hunter, Inc., a wholly owned subsidiary of the Company, entered into a purchase and sale agreement with Oasis Petroleum of North America LLC, or Oasis, to sell its non-operated working interest in certain oil and natural gas properties located in Burke County, North Dakota, to Oasis for $32.5 million in cash, subject to customary adjustments. The transaction closed on September 26, 2013, and was effective as of July 1, 2013. The Company recognized a loss of $38.1 million on the sale for the year ended December 31, 2013.
	On December 30, 2013, PRC Williston, LLC and Williston Hunter ND, LLC , subsidiaries of the Company, closed on the sale of certain assets to Enduro Operating LLC, (“Enduro”). The Enduro sale included certain oil and gas properties and assets located in Burke, Renville, Bottineau and McHenry Counties, North Dakota, including operated working interests in approximately 180 wells producing primarily from the Madison formation in the Williston Basin. The effective date of the sale was September 1, 2013. The total purchase price, after initial purchase price adjustments, was $44.1 million in cash. The Company recognized a preliminary loss of $8.2 million and final determination of the customary adjustments to the purchase price will be made by the parties approximately 120 days after closing.

FAIR_VALUE_OF_FINANCIAL_INSTRU

FAIR VALUE OF FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
FAIR VALUE OF FINANCIAL INSTRUMENTS	'
	NOTE 3 - FAIR VALUE OF FINANCIAL INSTRUMENTS
	Accounting standards define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The standards also establish a framework for measuring fair value and a valuation hierarchy based upon the transparency of inputs used in the valuation of an asset or liability.  Classification within the hierarchy is based upon the lowest level of input that is significant to the fair value measurement.  The valuation hierarchy contains three levels:
	●	Level 1 — Quoted prices (unadjusted) for identical assets or liabilities in active markets;
	●	Level 2 — Quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; and model-derived valuations whose inputs or significant value drivers are observable;
	●	Level 3 — Significant inputs to the valuation model are unobservable.
	The Company used the following fair value measurements for certain of its assets and liabilities during the years ended December 31, 2013 and 2012:
	Level 1 Classification:
	Available for Sale Securities
	At December 31, 2013, the Company held common and preferred stock of companies publicly traded on the TSX Venture Exchange and the NYSE MKT (formerly NYSE Amex) with quoted prices in active markets. Accordingly, the fair market value measurements of these securities have been classified as Level 1.
	Level 2 Classification:
	Commodity Derivative Instruments
	At December 31, 2013 and December 31, 2012, the Company had commodity derivative financial instruments in place.  The Company does not designate its derivative instruments as hedges and therefore does not apply hedge accounting.  Changes in fair value of derivative instruments subsequent to the initial measurement are recorded as gain (loss) on derivative contracts, in other income (expense).  The estimated fair values of the Company’s derivative instruments have been determined at discrete points in time based on relevant market information which resulted in the Company classifying such derivatives as Level 2.  Although the Company’s derivative instruments are valued using public indices, the instruments themselves are traded with unrelated counterparties and are not openly traded on an exchange.  See "Note 4 - Financial Instruments and Derivatives".
	As of December 31, 2013 and December 31, 2012, the Company’s derivative contracts were with financial institutions, all of which were either senior lenders to the Company or affiliates of such senior lenders, and some of which had investment grade credit ratings. All of the counterparties are believed to have minimal credit risk.  Although the Company is exposed to credit risk to the extent of nonperformance by the counterparties to these derivative contracts, the Company does not anticipate such nonperformance and monitors the credit worthiness of its counterparties on an ongoing basis.
	Level 3 Classification:
	Preferred Stock Embedded Derivative
	At December 31, 2013, the Company had preferred stock derivative liabilities resulting from certain conversion features, redemption options, and other features of its Series A Convertible Preferred Units of Eureka Hunter Holdings, LLC. See "Note 11 - Redeemable Preferred Stock".
	The preferred stock embedded derivative was valued using the “with and without” analysis in a simulation model. The key inputs used in the model to determine fair value at December 31, 2013 were a volatility of 25.0%, credit spread of 13.90%, and an estimated enterprise value of Eureka Hunter Holdings of $568.0 million.
	Convertible Security Embedded Derivative
	The Company recognized an embedded derivative asset resulting from the fair value of the bifurcated conversion feature associated with the convertible note received as partial consideration upon the sale of Hunter Disposal, LLC ("Hunter Disposal") to GreenHunter Resources, Inc. ("GreenHunter"), a related party. See "Note 2 - Divestitures and Discontinued Operations".  The convertible security embedded derivative was valued using a Black-Scholes model valuation of the conversion option.
	The key inputs used in the Black-Scholes option pricing model were as follows:
		31-Dec-13
	Life	3.1			years
	Risk-free interest rate	0.93			%
	Estimated volatility	40			%
	Dividend	—
	GreenHunter Resources Stock price at end of period	$	1.18
	The following table presents the changes in the fair value of the derivative assets and liabilities measured at fair value using significant unobservable inputs for the year ended December 31, 2013:
		Embedded Derivatives
		Series A Preferred Units				Convertible Security
		(in thousands)
	Fair value at December 31, 2012	$	(43,548	)		$	264
	Issued or acquired embedded derivative asset (liability)	(14,645		)		—
	Change in fair value recognized in other income (expense)	(17,741		)		(185		)
	Fair value as of December 31, 2013	$	(75,934	)		$	79
	The following tables present financial assets and liabilities which are adjusted to fair value on a recurring basis at December 31, 2013 and 2012:
		Fair Value Measurements on a Recurring Basis
		31-Dec-13
		(in thousands)
		Level 1				Level 2				Level 3
	Available for sale securities	$	1,819			$	—			$	—
	Commodity derivative assets	—				554				—
	Convertible security derivative assets	—				—				79
	Total assets at fair value	$	1,819			$	554			$	79
	Commodity derivative liabilities	$	—			$	2,279			$	—
	Convertible preferred stock derivative liabilities	—				—				75,934
	Total liabilities at fair value	$	—			$	2,279			$	75,934
		Fair Value Measurements on a Recurring Basis
		31-Dec-12
		(in thousands)
		Level 1				Level 2				Level 3
	Available for sale securities	$	1,958			$	—			$	—
	Commodity derivative assets	—				4,882				—
	Convertible security derivative assets	—				—				264
	Total assets at fair value	$	1,958			$	4,882			$	—
	Commodity derivative liabilities	$	—			$	7,477			$	—
	Convertible preferred stock derivative liabilities	—				—				43,548
	Total liabilities at fair value	$	—			$	7,477			$	43,548
	Other Fair Value Measurements
	The carrying value of the Company's senior revolving credit facility (the “MHR Senior Revolving Credit Facility") approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us for those periods.  The fair value hierarchy for the MHR Senior Revolving Credit Facility is Level 3.
	The fair value of the Company's Senior Notes is based on quoted market prices available for our senior notes.  The estimated fair value of the Company's Senior Notes as of December 31, 2013 and December 31, 2012 was $651.3 million and $613.5 million, respectively.  The fair value hierarchy for the Company's Senior Notes is Level 2 (quoted prices for similar assets in active markets).
	The fair value of Eureka Hunter Pipeline's second lien term loan is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.  The credit spread is the Company’s default or repayment risk.  The credit spread (premium or discount) is determined by comparing the Company’s fixed-rate notes and credit facility to new issuances (secured and unsecured) and secondary trades of similar size and credit statistics for both public and private debt.  The fair value of all fixed-rate notes and the credit facility is based on interest rates currently available to the Company.  Eureka Hunter Pipeline's second lien term loan is valued using an income approach and classified as Level 3 in the fair value hierarchy.
	The Company uses available market data and valuation methodologies to estimate the fair value of debt.  The carrying amounts and fair values of long-term debt are as follows:
			Fair Value		31-Dec-13								31-Dec-12
		Hierarchy Level		Carrying Amount				Estimated Fair Value				Carrying Amount		Estimated Fair Value
				(in thousands)
Senior Notes (1)		Level 2		$	597,230			$	651,300			$	597,212	$	613,500
MHR Senior Revolving Credit Facility (2)		Level 3		218,000				218,000				225,000		225,000
Eureka Hunter Pipeline, LLC second lien term loan (3)		Level 3		50,000				58,921				50,000		58,550
Equipment notes payable (3)		Level 3		18,615				17,676				18,548		17,450
________________________________
(1) The fair value of the Company's Senior Notes is based on quoted market prices.
(2) The carrying value of each of the MHR Senior Revolving Credit Facility and Magnum Hunter's second lien term loan approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us at such date.
(3) The fair value of (a) Eureka Hunter Pipeline’s second lien term loan and (b) equipment note payable, is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.
Fair Value on a Non-Recurring Basis
The Company follows the provisions of ASC 820-10 for nonfinancial assets and liabilities measured at fair value on a non-recurring basis. As it relates to Magnum Hunter, ASC 820-10 applies to certain nonfinancial assets and liabilities as may be acquired in a business combination and thereby measured at fair value; measurements of oil and natural gas property impairments; and the initial recognition of AROs, for which fair value is used. These ARO estimates are derived from historical costs as well as management's expectation of future cost environments. As there is no corroborating market activity to support the assumptions used, Magnum Hunter has designated these measurements as Level 3.
A reconciliation of the beginning and ending balances of Magnum Hunter's ARO is presented in "Note 7 - Asset Retirement Obligations".
New fair value measurements of proved oil and natural gas properties during the year ended December 31, 2013 and 2012 consist of:
Fair Value Measurements on a Non-recurring Basis
		(Level 1)				(Level 2)				(Level 3)
		(in thousands)
Proved properties impaired (1)		$	—			$	—			$	1,024
Total during the year ended December 31, 2013		$	—			$	—			$	1,024
Proved properties impaired (1)		$	—			$	—			$	58,082
Acquisitions (2)		—				—				532,150
Total during the year ended December 31, 2012		$	—			$	—			$	590,232
________________________________
(1) The Company recorded impairment charges from continuing operations of $10.0 million and $3.8 million during the years ended December 31, 2013 and 2012, respectively, as a result of writing down the carrying value of certain properties to fair value. In order to determine fair value, Magnum Hunter compares net capitalized costs of proved oil and natural gas properties to estimated undiscounted future net cash flows using management's expectations of economically recoverable reserves. If the net capitalized cost exceeds the undiscounted future net cash flows, Magnum Hunter impairs the net cost basis down to the discounted future net cash flows, which is management's estimate of fair value. Significant inputs used to determine the fair value include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average
cost of capital rate. The underlying commodity prices embedded in the Company's estimated cash flows are the product of a process that begins with third party analyst forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Magnum Hunter's management believes will impact realizable prices. The inputs used by management for the fair value measurements utilized in this review include significant unobservable inputs, and therefore, the fair value measurements employed are classified as Level 3 for these types of assets.
(2)Magnum Hunter records the fair value of assets and liabilities acquired in business combinations. During the year ended December 31, 2012, Magnum Hunter acquired oil and natural gas properties with a fair value of $532.2 million. Properties acquired are recorded at fair value, which correlates to the discounted future net cash flow. Significant inputs used to determine the fair value of proved properties include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. The underlying commodity prices embedded in the Company's estimated cash flows are the product of a process that begins with third party analyst forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Magnum Hunter's management believes will impact realizable prices. For acquired unproved properties, the market-based weighted average cost of capital rate is subjected to additional project specific risking factors. The inputs used by management for the fair value measurements of these acquired oil and natural gas properties include significant unobservable inputs, and therefore, the fair value measurements employed are classified as Level 3 for these types of assets.

FINANCIAL_INSTRUMENTS_AND_DERI

FINANCIAL INSTRUMENTS AND DERIVATIVES	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
FINANCIAL INSTRUMENTS AND DERIVATIVES	'
	NOTE 4 - FINANCIAL INSTRUMENTS AND DERIVATIVES
	The Company periodically enters into certain commodity derivative instruments such as futures contracts, swaps, collars, and basis swap contracts, which are effective in mitigating commodity price risk associated with a portion of its future monthly natural gas and crude oil production and related cash flows. The Company has not designated any of its commodity derivatives as hedges under ASC 815.
	In a commodities swap agreement, the Company trades the fluctuating market prices of oil or natural gas at specific delivery points over a specified period, for fixed prices. As a producer of oil and natural gas, the Company holds these commodity derivatives to protect the operating revenues and cash flows related to a portion of its future natural gas and crude oil sales from the risk of significant declines in commodity prices, which helps reduce exposure to price risk and improves the likelihood of funding its capital budget.  If the price of a commodity rises above what the Company has agreed to receive in the swap agreement, the amount that it agreed to pay the counterparty would theoretically be offset by the increased amount it received for its production.
	The Company also enters into three-way collars with third parties. These instruments typically establish two floors and one ceiling. Upon settlement, if the index price is below the lowest floor, the Company receives the difference between the two floors. If the index price is between the two floors, the Company receives the difference between the higher of the two floors and the index price. If the index price is between the higher floor and the ceiling, the Company does not receive or pay any amounts. If the index price is above the ceiling, the Company pays the excess over the ceiling price. The advantage to the Company of the three-way collar is that the proceeds from the second floor allow us to lower the total cost of the collar.
	The Company's failure to service any of its debt or to comply with any of its debt covenants (including failures stemming from its late SEC filings) could result in a default under the related debt agreement, and under any commodity derivative contract under which such debt default is a cross-default, which could result in the early termination of the commodity derivative contract (and an early termination payment obligation) and/or otherwise materially adversely affect its business, financial condition and results of operations.
	The table below is a summary of the Company's commodity derivatives as of December 31, 2013:
					Weighted Avg
	Natural Gas	Period	MMBtu/d		Price per MMBtu
	Swaps	Jan 2014 - Dec 2014	10,000		$4.13
	Ceilings purchased (call)	Jan 2014 - Dec 2014	10,000		$6.15
	Ceilings sold (call)	Jan 2014 - Dec 2014	26,000		$5.47
	Floors purchased (put)	Jan 2014 - Dec 2014	10,000		$4.25
	Floors sold (put)	Jan 2014 - Dec 2014	10,000		$3.75
					Weighted Avg
	Crude Oil	Period	Bbl/d		Price per Bbl
	Collars (1)	Jan 2014 - Dec 2014	663		$85.00 - $91.25
		Jan 2015 - Dec 2015	259		$85.00 - $91.25
	Traditional three-way collars (2)	Jan 2014 - Dec 2014	4,000		$64.94 - $85.00 - $102.50
	Ceilings sold (call)	Jan 2015 - Dec 2015	1,570		$120.00
	Floors sold (put)	Jan 2014 - Dec 2014	663		$65.00
		Jan 2015 - Dec 2015	259		$70.00
	________________________________
	(1) A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.
	(2) These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.
	Currently, Bank of Montreal, KeyBank National Association, Credit Suisse Energy, LLC, Bank of America - Merrill Lynch, Deutsche Bank AG London Branch, Citibank, N.A., J. Aron & Company, an affiliate of Goldman Sachs, are the only counterparties to the Company's commodity derivatives positions.  The Company is exposed to credit losses in the event of nonperformance by the counterparties on its commodity derivatives positions.  However, the Company does not anticipate nonperformance by the counterparties over the term of the commodity derivatives positions.  All counterparties or their affiliates are participants in the Company's senior revolving credit facility, and the collateral for the outstanding borrowings under its senior revolving credit facility is used as collateral for its commodity derivatives with those counterparties.
	At December 31, 2013, the Company has preferred stock derivative liabilities resulting from certain conversion features, redemption options, and other features of its Series A Convertible Preferred Units of Eureka Hunter Holdings, LLC. See "Note 3 - Fair Value of Financial Instruments" and "Note 10 - Shareholders' Equity".
	At December 31, 2013, the Company also has a convertible security embedded derivative asset primarily due to the conversion feature of the promissory note receivable from GreenHunter Resources, Inc. received as partial consideration for the sale of Hunter Disposal, LLC. See "Note 3 - Fair Value of Financial Instruments", "Note 2 - Divestitures and Discontinued Operations" and "Note 16 - Related Party Transactions".
	The following table summarizes the fair value of the Company's derivative contracts as of the dates indicated:
		Derivatives not designated as hedging instruments
		Gross Derivative Assets						Gross Derivative Liabilities
		December 31,						December 31,
		2013				2012		2013			2012
	Commodity	(in thousands)
	Derivative assets	$	529			$	4,882	$	—		$	—
	Derivatives assets, long term	25				—		—			—
	Derivative liabilities	—				—		(1,903		)	(3,501		)
	Derivative liabilities, long term	—				—		(376		)	(3,976		)
	Total commodity	$	554			$	4,882	$	(2,279	)	$	(7,477	)
	Financial
	Derivative assets	$	79			$	264	$	—		$	—
	Derivative liabilities, long term	—				—		(75,934		)	(43,548		)
	Total financial	$	79			$	264	$	(75,934	)	$	(43,548	)
	Total derivatives	633				5,146		(78,213		)	(51,025		)
	The following table summarizes the net gain (loss) on all derivative contracts included in other income (expense) on the consolidated statements of operations for the years ended December 31, 2013, 2012 and 2011:
		For the Year Ended December 31,
		2013				2012		2011
		(in thousands)
	Gain (loss) on settled transactions	$	(8,216	)		$	11,294	$	(2,136	)
	Gain (loss) on open transactions	(17,058		)		10,945		(4,210		)
	Total gain (loss)	$	(25,274	)		$	22,239	$	(6,346	)

ACQUISITIONS

ACQUISITIONS	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
ACQUISITIONS	'
	NOTE 5 - ACQUISITIONS
	The Company has recognized $2.8 million, $4.7 million, and $8.9 million of transaction expenses related to acquisitions in its general and administrative expenses for the years ended December 31, 2013, 2012, and 2011, respectively. Substantially all of the Company's acquisitions contained a significant amount of unproved acreage, as is consistent with the Company's business strategy.
	Utica Shale Assets Acquisition
	On February 17, 2012, the Company closed on the acquisition of leasehold mineral interests located predominately in Noble County, Ohio for a total purchase price of $24.8 million in cash.
	Eagle Operating Assets Acquisition
	On March 30, 2012, the Company, through its wholly-owned subsidiary, Williston Hunter ND, LLC, a Delaware limited liability company (“Williston Hunter”), closed on the purchase of operating working interest in certain oil and gas leases and wells located in several counties in North Dakota from Eagle Operating, Inc. (“Eagle Operating”), an unrelated third party, effective April 1, 2011.  Total consideration was $52.9 million consisting of $51.0 million in cash and 296,859 shares of Magnum Hunter restricted common stock valued at $1.9 million based on a price of $6.41 per share. The purpose of the acquisition was to expand the Company’s position in the Williston Basin. The Company already owned a non-operated ownership interest in the properties acquired.
	The acquisition was accounted for using the acquisition method of accounting, which requires the net assets acquired to be recorded at their fair values. The following table summarizes the purchase price and the estimates of fair values of the net assets acquired (in thousands, except shares and per share information):
	Fair value of total purchase price:
	296,859 shares of common stock issued on March 30, 2012 at $6.41 per share	$	1,902
	Cash	50,974
	Total	$	52,876
	Amounts recognized for assets acquired and liabilities assumed:
	Oil and gas properties	$	54,832
	ARO	(1,956		)
	Total	$	52,876
	TransTex Gas Services, LP Assets Acquisition
	On April 2, 2012, the Company, through its majority owned subsidiary, Eureka Hunter Holdings, LLC, and its wholly-owned subsidiary, Eureka Hunter Acquisition Sub, LLC, closed on their purchase of certain assets of TransTex Gas Services, LP (“TransTex”), a related third party, under an asset purchase agreement dated March 21, 2012, which resulted in the recognition of approximately $30.6 million in goodwill and $10.5 million of intangible assets.  See "Note 6 - Goodwill and Intangible Assets". The Company expects all of the goodwill, which is associated with the Company’s midstream operating segment, to be deductible for tax purposes.  The purpose of the acquisition was to complement the Company’s existing midstream assets.  The total purchase price paid for the acquired assets was $58.5 million, comprised of $46.0 million in cash and 622,641 Eureka Hunter Holdings Class A Common Units representing membership interests in Eureka Hunter Holdings, with a value of $12.5 million based on an estimated enterprise value of $400.0 million at that time determined utilizing a discounted future cash flow analysis.
	The following table summarizes the purchase price and the estimates of fair values of the net assets acquired from TransTex (in thousands):
	Fair value of total purchase price:
	Cash	$	46,047
	Eureka Hunter Holdings Class A Common Units	12,453
	Total	$	58,500
	Amounts recognized for assets acquired and liabilities assumed:
	Working capital	$	525
	Equipment and other fixed assets	15,575
	Other assets	1,306
	Goodwill (Note 8)	30,602
	Intangible assets (Note 8)	10,492
	Total	$	58,500
	Gary C. Evans, the Company's Chairman and CEO, previously held a small limited partnership interest in TransTex, and participated in the purchase of certain Eureka Hunter Holdings Class A Common Units offered to all limited partners of TransTex in connection with the acquisition. See "Note 16 - Related Party Transactions".
	Baytex Energy USA Assets Acquisition
	On May 22, 2012, the Company, through its wholly-owned subsidiary, Bakken Hunter, LLC, closed on the acquisition of certain Williston Basin assets of Baytex Energy USA, Ltd. (“Baytex Energy USA”), an affiliate of Baytex Energy Corporation, an unrelated third party, for a total purchase price of $312.0 million.  The purpose of the acquisition was to significantly increase the Company’s ownership interest in existing mineral leases in a key shale play where the Company has increased its drilling activities. To a lesser extent, proved reserves were added attributable to the acquired properties. The acquired assets include all of Baytex Energy USA’s non-operated working interest in oil and gas properties and wells located in Divide and Burke Counties, North Dakota, within an area subject to an operating agreement among Samson Resources Company, as operator, Baytex Energy Corporation, and Williston Hunter, Inc., a wholly-owned subsidiary of Magnum Hunter.
	The following table summarizes the purchase price and the preliminary estimates of fair values of the net assets acquired (in thousands):
	Fair value of total purchase price:
	Cash	$	312,018
	Total	$	312,018
	Amounts recognized for assets acquired and liabilities assumed:
	Oil and gas properties	$	312,294
	ARO	(276		)
	Total	$	312,018
	Acquisition of Viking International Resources Co., Inc.
	On November 2, 2012, Triad Hunter, LLC, a wholly-owned subsidiary of the Company, closed on the acquisition of all outstanding capital stock of Viking International Resources Co., Inc. (“Virco”) effective January 1, 2012.  The total fair market value of consideration paid was approximately $100.8 million, made up of approximately $37.3 million paid in cash and 2,774,850 depositary shares representing 2,774.85 shares of 8.0% Series E Cumulative Convertible Preferred Stock of the Company with market value of approximately $65.2 million and stated liquidation preference of approximately $69.4 million. See "Note 10 - Shareholders' Equity" regarding the Series E Preferred Stock. The primary purpose of the acquisition was to acquire leasehold acreage and wells complementary to the Company's existing acreage position of this region and expand its ownership interest in the Marcellus Shale and Utica Shale plays in West Virginia and Ohio.
	The following table summarizes the purchase price and the preliminary estimates of fair values of the net assets acquired (in thousands):
	Fair value of total purchase price:
	Cash	$	37,349
	2,774,850 depositary shares evidencing Series E Preferred Stock issued on November 2, 2012, valued at $23.50 per share	65,209
	Escrow settlement	(1,750		)
	Total	$	100,808
	Amounts recognized for assets acquired and liabilities assumed:
	Oil and gas properties	$	110,224
	Current assets	1,676
	Equipment and other fixed assets	970
	Accounts payable and accrued expenses	(3,928		)
	Other long-term liabilities	(2,362		)
	ARO	(5,772		)
	Total	$	100,808
	Samson Resources Assets Acquisition
	On December 20, 2012, Bakken Hunter, LLC, a wholly-owned subsidiary of the Company, closed on the acquisition of certain existing wells and Williston Basin lease acres located in Divide County, North Dakota from Samson Resources Company. The purchase price for the assets was $30.0 million in cash, subject to customary adjustments. The effective date of the transaction was August 1, 2012.
	With the closing of this transaction, the Company owns varied working ownership interests in these properties up to approximately 100%. The acquisition established the Company as an operator in certain of this Bakken acreage, covering four Townships and Ranges in northern Divide County, North Dakota, previously operated by Samson Resources Company.
	Agreement to Purchase Utica Shale Acreage
	On August 12, 2013, Triad Hunter entered into an asset purchase agreement, with MNW. MNW is an Ohio limited liability company that represents an informal association of various land owners, lessees and sub-lessees of mineral acreage who own or have rights in mineral acreage located in Monroe, Noble and/or Washington Counties, Ohio. Pursuant to the purchase agreement, Triad Hunter has agreed to acquire, subject to certain conditions, from MNW up to 32,000 net mineral acres, including currently leased and subleased acreage, located in such counties, over the next 10 months or possibly longer. The maximum purchase price, if MNW delivers 32,000 acres with acceptable title, would be $142.1 million, excluding title costs. During 2013, Triad Hunter purchased leasehold acreage from MNW for an aggregate purchase price of $24.5 million.
	The following summarizes the revenue and operating income (loss) from the acquisitions included in the Company's consolidated statements of operations for the years ended December 31, 2013 and 2012:
		For the year ended December 31,
	2013							2012
	Revenues				Operating Income (loss)			Revenues		Operating Income (loss)
	(in thousands)							(in thousands)
Eagle Operating assets	$	7,331			$	(26,867	)	$	5,500	$	(3,019	)
TransTex assets	$	12,765			$	(812	)	$	7,014	$	(393	)
Baytex Energy USA assets	$	100,572			$	(101,627	)	$	18,430	$	(6,649	)
VIRCO acquisition	$	4,453			$	(177	)	$	1,094	$	450
The following unaudited summary, prepared on a pro forma basis, presents the results of operations for the year ended December 31, 2012, as if the above acquisitions along with transactions necessary to finance the acquisitions, had occurred as of the beginning of 2012. The pro forma information includes the effects of adjustments for interest expense, depreciation and depletion expense, and dividend expense. The pro forma results are not necessarily indicative of what actually would have occurred if the acquisition had been completed as of the beginning of each period presented, nor are they necessarily indicative of future consolidated results. The Company determined that pro forma presentation of the leasehold acreage acquired from MNW was not necessary, as the acquisitions were not significant to its balance sheet and the undeveloped acreage had no operating results.
	Pro Forma
	For the Year Ended December 31,
		2012
	(in thousands except for per share amount, unaudited)
Total revenue		$	159,085
Operating loss		(108,177		)
Net loss		(150,777		)
Net loss attributable to Magnum Hunter Resources Corporation		(146,764		)
Net loss attributable to common shareholders		$	(188,736	)
Loss per common share, basic and diluted		$	(1.21	)

GOODWILL_AND_INTANGIBLE_ASSETS

GOODWILL AND INTANGIBLE ASSETS	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
GOODWILL AND INTANGIBLE ASSETS	'
	NOTE 6 - GOODWILL AND INTANGIBLE ASSETS
	Goodwill
	Goodwill represents the excess of the purchase price of an entity over the estimated fair value of the assets acquired and the liabilities assumed. The Company assesses the carrying amount of goodwill by testing the goodwill for impairment annually or whenever interim impairment indicators arise.  Goodwill of $30.6 million was recorded related to the Company's midstream segment during 2012 as a result of its acquisition of the assets of TransTex Gas Services, LP, discussed in "Note 5 - Acquisitions". The Company assessed goodwill for impairment on April 1, 2013, and determined that no impairment existed. The Company updated its annual impairment test through December 31, 2013, with an evaluation of any triggering events or circumstances that would indicate that impairment of the carrying value of goodwill is likely, and none were determined to exist.
	Intangible Assets
	Intangible assets consist primarily of the fair value of the acquired gas treating agreements and customer relationships in the TransTex Gas Services, LP assets acquisition completed in 2012.  The intangible assets were valued at fair value using a discounted cash flow model with a discount rate of 13%.  Such assets are being amortized over the weighted average term of 8.54 years.
	The following table summarizes the Company's changes in intangible assets during the years ended December 31, 2013 and 2012:
		Amortization			December 31,			December 31,
		Period			2013			2012
					(in thousands)
	Intangible assets, at beginning of the period				$	10,492		$	—
	Additions through acquisition:
	Customer relationships	12.5	years		—			5,434
	Trademark	11	years		—			859
	Existing contracts	2.9	years		—			4,199
	Total intangible assets				10,492			10,492
	Accumulated amortization:
	Customer relationships				(1,248		)	(326		)
	Trademark				(137		)	(58		)
	Existing contracts				(2,577		)	(1,127		)
	Intangible assets, net of accumulated amortization				$	6,530		$	8,981
	The following table summarizes the aggregate amortization of intangible assets over the next five years:
			(in thousands)
	2014		$	2,007
	2015		$	981
	2016		$	586
	2017		$	519
	2018		$	457
	Thereafter		$	1,980

ASSET_RETIREMENT_OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
ASSET RETIREMENT OBLIGATIONS	'
	NOTE 7 - ASSET RETIREMENT OBLIGATIONS
	The Company's ARO primarily represents the estimated present value of the amount the Company will incur to plug, abandon and remediate its producing properties at the end of their productive lives, in accordance with applicable federal, state and local laws. The Company determined its ARO by calculating the present value of estimated cash flows related to the liability. The retirement obligation is recorded as a liability at its estimated present value as of the asset’s inception, with a corresponding increase to proved properties. The Company records accretion of the estimated liability as accretion expense in depreciation, depletion, amortization, and accretion in the consolidated statements of operations.
	The Company's liability is determined using significant assumptions, including current estimates of plugging and abandonment costs, annual inflation of these costs, the productive lives of wells and its risk-adjusted interest rate. Changes in any of these assumptions can result in significant revisions to the estimated ARO. Revisions to the ARO are recorded with a corresponding change to producing properties, resulting in prospective changes to depreciation, depletion and amortization expense and accretion of discount. Because of the subjectivity of assumptions and the relatively long lives of most of the Company's wells, the costs to ultimately retire its wells may vary significantly from prior estimates. The Company's liability for AROs was approximately $16.2 million and $30.7 million at December 31, 2013 and 2012, respectively.
	The Company's midstream operating assets generally consist of underground pipelines and related components along rights-of-way and above ground storage tanks and related facilities. The Company's right-of-way agreements typically do not require the dismantling, removal and reclamation of the right-of-way upon permanent cessation of pipeline service. Additionally, management is unable to predict when, or if, the Company's pipelines, storage tanks and related facilities would become completely obsolete and require decommissioning. Accordingly, the Company has recorded no liability or corresponding asset as an ARO as both the amounts and timing of such future costs are indeterminable.
	The following table summarizes the changes in the Company’s ARO transactions during the years ended December 31, 2013 and 2012:
		2013			2012
		(in thousands)
	Asset retirement obligation at beginning of period	$	30,680		$	20,584
	Assumed in acquisition	17			8,027
	Liabilities incurred	253			373
	Liabilities settled	(98		)	(80		)
	Liabilities associated with assets sold	(7,614		)	—
	Accretion expense	2,264			1,671
	Revisions in estimated liabilities	1,935			76
	Reclassified as liabilities associated with assets held for sale	(11,148		)	13
	Effect of foreign currency translation	(73		)	16
	Asset retirement obligation at end of period	16,216			30,680
	Less: current portion	(53		)	(2,358		)
	Asset retirement obligation at end of period	$	16,163		$	28,322

LONGTERM_DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
LONG-TERM DEBT	'
	NOTE 8 - LONG-TERM DEBT
	Notes payable at December 31, 2013 and 2012 consisted of the following:
		As of December 31,
		2013			2012
		(in thousands)
	Senior Notes Payable due May 15, 2020, interest rate of 9.75%, net of unamortized discount of $2.8 million at December 31, 2013 and 2012	$	597,230		$	597,212
	Various equipment and real estate notes payable with maturity dates February 2015 - November 2017, interest rates of 4.25% - 5.70% (1)	18,615			18,548
	Eureka Hunter Pipeline, LLC second lien term loan due August 16, 2018, interest rate of 12.5%	50,000			50,000
	MHR Senior revolving credit facility due April 13, 2016, interest rate of 3.42% at December 31, 2013 and 3.56% at December 31, 2012	218,000			225,000
		$	883,845		$	890,760
	Less: current portion	(3,967		)	(3,991		)
	Total long-term debt	$	879,878		$	886,769
	_________________
	(1) Includes notes classified as liabilities associated with assets held for sale of which $163,000 is current and $3.8 million is long term
	The following table presents the approximate annual maturities of debt, gross of unamortized discount:
		(in thousands)
	2014	$	3,967
	2015	7,940
	2016	224,378
	2017	330
	2018	50,000
	Thereafter	597,230
		$	883,845
	Senior Notes
	On May 16, 2012, the Company completed the issuance of $450.0 million aggregate principal amount of its 9.75% Unregistered Senior Notes which mature on May 15, 2020 for total proceeds of $431.2 million net of issuing costs of $12.8 million, resulting in a discount of $6.0 million.
	On December 13, 2012, the Company completed the issuance of an additional $150.0 million aggregate principal amount of its 9.75% Unregistered Senior Notes for total proceeds of $149.9 million net of issuing costs of $3.1 million, resulting in a premium of $3.0 million.
	On November 8, 2013 we completed an exchange offer pursuant to which we exchanged $600 million of Senior Notes registered under the Securities Act for all of the Unregistered Notes. We refer to the exchange Senior Notes as the Exchange Notes or our Senior Notes. The Exchange Notes have substantially identical terms to our former Unregistered Senior Notes except the Exchange Notes are generally freely transferable under the Securities Act.
	The Senior Notes are unsecured and are guaranteed, jointly and severally, on a senior unsecured basis by certain of the Company’s domestic subsidiaries. The indenture governing the Senior Notes permits a guarantor of the Senior Notes to be released from its guarantee under certain circumstances, including in connection with a sale or other disposition of all or substantially all of the assets of the guarantor, a sale of other disposition of the capital stock of the guarantor to a third party, or upon the liquidation or dissolution of the guarantor.
	Interest on the Senior Notes is paid semi-annually in arrears on May 15 and November 15 of each year. The Company paid penalty interest totaling $1.1 million during 2013 due to its untimely filing of a Registration Statement on Form S-4 to consummate an exchange offer.
	The Company used the net proceeds of the Senior Notes, together with other sources of liquidity, (i) to finance a portion of the $312.0 million acquisition of oil properties in the Williston Basin from Baytex Energy USA, Ltd., which closed on May 22, 2012, (ii) to pay off all amounts outstanding under the Company’s second lien term loan, (iii) to repay outstanding debt under the Company’s senior revolving credit facility, (iv) for capital expenditures and (v) general corporate purposes.
	The Senior Notes were issued pursuant to an indenture entered into on May 16, 2012 as supplemented, among the Company, the subsidiary guarantors party thereto, Wilmington Trust, National Association, as the trustee, and Citibank, N.A., as the paying agent, registrar and authenticating agent.  The terms of the Senior Notes are governed by the indenture, which contains affirmative and restrictive covenants that, among other things, limit the Company’s and the guarantors’ ability to incur or guarantee additional indebtedness or issue certain preferred stock; pay dividends on capital stock or redeem, repurchase or retire capital stock or subordinated indebtedness or make certain other restricted payments; transfer or sell assets; make loans and other investments; create or permit to exist certain liens; enter into agreements that restrict dividends or other payments from restricted subsidiaries to the Company; consolidate, merge or transfer all or substantially all of their assets; engage in transactions with affiliates; and create unrestricted subsidiaries.
	The indenture also contains events of default.  Upon the occurrence of events of default arising from certain events of bankruptcy or insolvency, the Senior Notes shall become due and payable immediately without any declaration or other act of the trustee or the holders of the Senior Notes.  Upon the occurrence of certain other events of default, the trustee or the holders of at least 25% in aggregate principal amount of the then outstanding Senior Notes may declare all outstanding Senior Notes to be due and payable immediately.
	At December 31, 2013, the Company was in compliance with all of its requirements under the indenture related to the Senior Notes.
	The Senior Notes are redeemable by the Company at any time on or after May 15, 2016, at the redemption price of 104.875%, after May 15, 2017, at the redemption price of 102.438%, and after May 15, 2018, at the redemption price of 100.00%. The Senior Notes are redeemable by the Company prior to May 15, 2016 at the redemption price equal to 100.00% of the principal amount of the notes redeemed, plus a “make-whole” premium of the greater of:
	(1)1.0% of the principal amount of the note; and
	(2)The excess of:
	(a)	The present value at such redemption date of (i) the redemption price of the note at May 15, 2016 plus (ii) all required interest payments due on the note through May 15, 2016 (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the treasury rate as of such redemption date plus 50 basis points discounted to such redemption date on a semi-annual basis, over
	(b)	The principal amount of the note.
	The Company is also entitled to redeem up to 35% of the aggregate principal amount of the Senior Notes before May 15, 2015 with net proceeds that the Company raises in certain equity offerings at a redemption price of 109.750%, so long as at least 65% of the aggregate principal amount of the Senior Notes issued under the indenture (excluding Senior Notes held by the Company) remains outstanding immediately after such redemption and the redemption occurs within 180 days of the closing date of such equity offering.  If the Company experiences certain change of control events, each holder of Senior Notes may require the Company to repurchase all or a portion of the Senior Notes for cash at a price equal to 101% of the aggregate principal amount of such Senior Notes, plus any accrued and unpaid interest up to, but not including the date of repurchase.
	Eureka Hunter Pipeline Credit Facilities
	On August 16, 2011, Eureka Hunter Pipeline, LLC (“Eureka Hunter Pipeline ”), a majority-owned subsidiary of the Company, entered into (i) a First Lien Credit Agreement (the “First Lien Agreement”) by and among Eureka Hunter Pipeline, the lenders party thereto and SunTrust Bank, as administrative agent, and (ii) a Second Lien Term Loan Agreement (the “Second Lien Agreement”), by and among Eureka Hunter Pipeline, the lenders party thereto and U.S. Bank National Association, as collateral agent (the First Lien Agreement and the Second Lien Agreement being collectively referred to as the “Eureka Credit Agreements”).
	The First Lien Agreement provides for a revolving credit facility (the “Revolver”) in an aggregate principal amount of up to $100 million (with an initial committed amount of $25 million), secured by a first lien on substantially all of the assets of Eureka Hunter Pipeline. The Second Lien Agreement provides for a $50 million term loan facility (the “Term Loan”), secured by a second lien on substantially all of the assets of Eureka Hunter Pipeline. The entire $50 million Term Loan had previously been drawn.  As of May 1, 2013, the revolving credit facility was not available due to the Company's inability to satisfy certain financial ratios included in the agreement. The Revolver has a maturity date of August 16, 2016, and the Term Loan has a maturity date of August 16, 2018. Both the Revolver and the Term Loan are non-recourse to Magnum Hunter Resources Corporation. See "Effect of Late SEC Filings on Liquidity and Capital Resources."
	The terms of the First Lien Agreement provide that the Revolver may be used for (i) revolving loans, (ii) swingline loans in an aggregate amount of up to $5 million at any one time outstanding, or (iii) letters of credit in an aggregate amount of up to $5 million at any one time outstanding. The Revolver provides for a commitment fee of 0.5% per annum based on the unused portion of the commitment under the Revolver.
	Borrowings under the Revolver will, at Eureka Hunter Pipeline’s election, bear interest at:
	•	a base rate equal to the highest of (i) the prime lending rate announced from time to time by the Administrative Agent, (ii) the then-effective Federal Funds Rate (as definited in the Eureka Hunter Pipeline Revolver) plus 0.5% per annum, or (iii) the Adjusted LIBO Rate (as defined in the First Lien Agreement) for a one-month interest period on such day plus 1.0% per annum, plus an applicable margin ranging from 1.25% to 2.25%; or
	•	the Adjusted LIBO Rate, plus an applicable margin ranging from 2.25% to 3.5%.
	Borrowings under the Term Loan will bear interest at 12.50% per annum in cash (increasing to 13.50% on and at all times when Eureka Hunter Pipeline and its subsidiaries incur indebtedness (other than the Term Loan) in excess of $1 million).
	If an event of default occurs under either the Revolver or the Term Loan, the lenders may increase the interest rate then in effect by an additional 2.0% per annum for the period that the default exists under the Revolver or the Term Loan.
	The Eureka Credit Agreements contain negative covenants that, among other things, restrict the ability of Eureka Hunter Pipeline and its subsidiaries to, with certain exceptions: (1) incur indebtedness; (2) grant liens; (3) dispose of all or substantially all of its assets or enter into mergers, consolidations, or similar transactions; (4) change the nature of its business; (5) make investments, loans, or advances or guarantee obligations; (6) pay cash dividends or make certain other payments; (7) enter into transactions with affiliates; (8) enter into sale and leaseback transactions; (9) enter into hedging transactions; (10) amend its organizational documents or material agreements; or (11) make certain undisclosed capital expenditures.
	The Eureka Credit Agreements also require Eureka Hunter Pipeline to satisfy certain financial covenants, including maintaining:
	•	a consolidated total debt to capitalization ratio of not more than 60%;
	•	a ratio of consolidated EBITDA to consolidated interest expense, in each case, for the four fiscal quarter period then ended ranging from:
	(i) for the Term Loan, not less than (A) 2.25 to 1.00, for the fiscal quarters ending December 31, 2013 and March 31, 2014, (B) 2.50 to 1.00, for the fiscal quarters ending June 30, 2014 and September 30, 2014, and (C) 2.75 to 1.0 for the fiscal quarter ending December 31, 2014 and each fiscal quarter ending thereafter, and
	(ii) in the event any portion of the Revolver has been drawn, for the Revolver, not less (A) 2.50 to 1.00, for the fiscal quarters ending December 31, 2013 and March 31, 2014, (B) 2.75 to 1.00, for the fiscal quarters ending June 30, 2014 and September 30, 2014, and (C) 3.00 to 1.0 for the fiscal quarter ending December 31, 2014 and each fiscal quarter ending thereafter;
	•	a ratio of consolidated total debt to consolidated EBITDA for the four fiscal quarter period then ended ranging from:
	(i) for the Term Loan, not greater than (A) 4.50 to 1.0 for the fiscal quarters ending December 31, 2013, March 31, 2014, June 30, 2014, and September 30, 2014, and (B) 4.25 to 1.0 for the fiscal quarter ending December 31, 2014 and each fiscal quarter ending thereafter, and
	(ii) in the event any portion of the Revolver has been drawn, for the Revolver, not greater than (A) 4.50 to 1.0 for the fiscal quarters ending December 31, 2013 and March 31, 2014, and (B) 4.00 to 1.0 for the fiscal quarter ending June 30, 2014 and each fiscal quarter ending thereafter; and
	•	a ratio of consolidated debt under the Revolver to consolidated EBITDA of (i) for the Term Loan, not greater than 3.5 to 1.0, and (ii) for the Revolver, if any portion of the Revolver has been drawn, not greater than 3.25 to 1.0 for each fiscal quarter.
	The obligations of Eureka Hunter Pipeline under each of the Revolver and the Term Loan may be accelerated upon the occurrence of an Event of Default (as such term is defined in such Eureka Credit Agreement) under such Eureka Credit Agreement. Events of Default include customary events for these types of financings, including, among others, payment defaults, defaults in the performance of affirmative or negative covenants, the inaccuracy of representations or warranties, defaults under the Term Loan (with respect to the Revolver) or the Revolver (with respect to the Term Loan), defaults relating to judgments, material defaults under certain material contracts of Eureka Hunter Pipeline, and defaults by the Company which cause the acceleration of the Company’s debt under its existing MHR Senior Revolving Credit Facility.
	Under the Eureka Credit Agreements, (i) Eureka Hunter Pipeline and its subsidiaries have entered into customary ancillary agreements and arrangements, which provide that the obligations under the Eureka Credit Agreement are secured by substantially all of the assets of Eureka Hunter Pipeline and such subsidiaries, consisting primarily of pipelines, pipeline rights-of-way, and gas treating and processing equipment and certain other equipment, and (ii) Eureka Hunter Holdings, the sole parent of Eureka Hunter Pipeline and a majority owned subsidiary of the Company, entered into customary ancillary agreements and arrangements, which granted the lenders under the Eureka Credit Agreements a non-recourse security interest in Eureka Hunter Holdings' equity interests in Eureka Hunter Pipeline.
	Availability under the Revolver is subject to satisfaction of certain financial covenants that are tested on a quarterly basis.
	At December 31, 2013, the Company was in compliance with all of its covenants, as amended or waived, contained in the Eureka Hunter Pipeline credit facilities.
	Eureka Hunter Pipeline had loans outstanding under this second lien facility of $50.0 million as of December 31, 2013 and 2012.
The Amended and Restated Limited Liability Company Agreement of Eureka Hunter Holdings, referred to as the EH Operating Agreement, contains certain covenants that, among other things, restrict the ability of Eureka Hunter Holdings and its subsidiaries, including Eureka Hunter Pipeline and TransTex Hunter, LLC, to, with certain exceptions:
•	incur funded indebtedness, whether direct or contingent;
•	issue additional equity interests;
•	pay distributions to its owners, or repurchase or redeem any of its equity securities;
•	make any material acquisitions, dispositions or divestitures; or
•	enter into a sale, merger, consolidation or other change of control transaction.
Revolving Credit Facility
On December 13, 2013, the Company entered into a Third Amended and Restated Credit Agreement (the “Credit Agreement”) by and among the Company, Bank of Montreal, as Administrative Agent, the lenders party thereto and the agents party thereto. The Credit Agreement amended and restated that certain Second Amended and Restated Credit Agreement, dated as of April 13, 2011, by and among such parties, as amended (the "Prior Credit Agreement"). The terms of the Credit Agreement are substantially similar to the Prior Credit Agreement.
The Credit Agreement provides for an asset-based, senior secured revolving credit facility maturing April 13, 2016 (the "Revolving Facility"). As of December 31, 2013 the borrowing base under the Revolving Facility was $242.5 million. The Revolving Facility is governed by a semi-annual borrowing base redetermination derived from the Company's proved crude oil and natural gas reserves, and based on such redeterminations, the borrowing base may be decreased or increased up to a maximum commitment level of $750 million. The borrowing base is subject to such periodic redeterminations commencing May 1, 2014.
The terms of the Credit Agreement provide that the Revolving Facility may be used for loans, and subject to a $10.0 million sublimit,
letters of credit. The Credit Agreement provides for a commitment fee of 0.5% of the unused portion of the borrowing base and commitments under the Revolving Facility.
Borrowings under the Revolving Facility will, at the Company’s election, bear interest at either (i) an alternate base rate (“ ABR ”)
equal to the highest of (A) the Prime Rate (as defined in the Credit Agreement) in effect on such day, (B) the Federal Funds Effective Rate (as defined in the Credit Agreement) in effect on such day, plus 0.5% per annum, and (C) the LIBO Rate (as defined in the Credit Agreement) for a one month interest period on such day, plus 1.00% or (ii) the Adjusted LIBO Rate (as defined in the Credit Agreement) for one, two, three, six or twelve months (as the Company may elect), plus, in each of the cases described in clauses (i) and (ii), an applicable margin ranging from 1.5% to 2.25% for ABR loans and from 2.5% to 3.25% for Adjusted LIBO Rate loans. Overdue amounts shall bear interest at a rate equal to 2.00% per annum plus the rate applicable to ABR loans.
The Credit Agreement contains negative covenants that, among other things, restrict the ability of the Company and its restricted
subsidiaries to, with certain exceptions, (i) incur indebtedness, (ii) grant liens, (iii) make certain payments, (iv) change the nature of its business, (v) dispose of all or substantially all of its assets or enter into mergers, consolidations or similar transactions, (vi) make investments, loans or advances, (vii) pay dividends, unless certain conditions are met, and with respect to the payment of dividends on preferred stock, subject to (A) no Event of Default (as defined in the Credit Agreement) existing, (B) after giving effect to any such preferred stock dividend payment, the Company maintaining availability under the borrowing base in an amount greater than the greater of (x) 2.50% percent of the borrowing base then in effect or (y) $5,000,000 and (C) a “basket” of $45,000,000 per year, and (viii) enter into transactions with affiliates.
In addition, the Credit Agreement requires the Company and its restricted subsidiaries to satisfy certain financial covenants, including maintaining:
(i) a ratio of consolidated current assets to consolidated current liabilities of not less than 1.0 to 1.0 as of the last day of any fiscal quarter;
(ii) a ratio of EBITDAX (as defined in the Credit Agreement) for the trailing four fiscal quarter period then ended to Interest Expense (as defined in the Credit Agreement) for such period of not less than (A) 2.00 to 1.00 for the fiscal quarter ending December 31, 2013, (B) 2.25 to 1.00 for the fiscal quarter ending March 31, 2014 and (C) 2.50 to 1.00 for the fiscal quarter ending June 30, 2014 and for each fiscal quarter ending thereafter; provided that solely for calculating such ratio for the fiscal quarter ending December 31, 2013, EBITDAX and interest expense for that fiscal quarter shall be calculated on an actual basis without giving effect to any pro forma adjustments;
(iii) beginning with the fiscal quarter ending June 30, 2014, a ratio of total debt to EBITDAX for the trailing four fiscal quarter period then ended of not more than (A) 4.50 to 1.0 for the fiscal quarters ending June 30, 2014 and September 30, 2014 and (B) 4.25 to 1.0 for the fiscal quarter ending December 31, 2014 and for each fiscal quarter ending thereafter; and
(iv) as of the last day of any fiscal quarter period ending through March 31, 2014, a ratio of total debt (less the outstanding principal amount of the Company’s 9.750% Senior Notes due 2020) to EBITDAX for the trailing four fiscal quarter period then ended of not more than 2.00 to 1.00.
At December 31, 2013, the Company was in compliance with all of its covenants, as amended or waived, contained in the Revolving Facility.
The obligations of the Company under the Credit Agreement may be accelerated upon the occurrence of an Event of Default. Events of Default include customary events for a financing agreement of this type, including, without limitation, payment defaults, defaults in the performance of affirmative or negative covenants, the inaccuracy of representations and warranties, bankruptcy or related defaults, defaults relating to judgments and the occurrence of a Change of Control (as defined in the Credit Agreement), subject, in certain circumstances, to certain cure periods.
Subject to certain permitted liens, the Revolving Facility is secured by the grant of a first priority lien on all or substantially all of the assets of the Company and its restricted subsidiaries, including, without limitation, a lien on no less than 80% of the value of the proved oil and gas properties of the Company and its restricted subsidiaries. In connection with the Credit Agreement, the Company and its restricted subsidiaries also entered into customary ancillary agreements and arrangements, which among other things, provide that the Revolving Facility is unconditionally guaranteed by such restricted subsidiaries.
Interest Expense
The following table sets forth interest expense for the years ended December 31, 2013 and 2012:
	Years Ended
	December 31,
	2013			2012
	(in thousands)
Interest expense incurred on debt, net of amounts capitalized	$	67,605		$	44,216
Amortization and write-off of deferred financing costs	4,818			7,400
Total Interest Expense	$	72,423		$	51,616
The Company capitalizes interest on expenditures for significant construction projects that last more than six months while activities are in progress to bring the assets to their intended use. Interest of $2.6 million and $4.4 million was capitalized on our Eureka Hunter Gas Gathering System during the years ended 2013 and 2012, respectively. The Company did not capitalize any interest in 2011.

SHAREBASED_COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
SHARE-BASED COMPENSATION	'
	NOTE 9 - SHARE-BASED COMPENSATION
	Employees, directors and other persons who contribute to the success of Magnum Hunter are eligible for grants of common stock, common stock options, and stock appreciation rights under the Company's amended and restated Stock Incentive Plan. At December 31, 2013, 27,500,000 shares of the Company's common stock are authorized to be issued under the plan, and 5,360,176 shares have been issued as of December 31, 2013.
	The Company recognized share-based compensation expense of $13.6 million, $15.7 million, and $25.1 million for the years ended December 31, 2013, 2012, and 2011 respectively.
	A summary of stock option and stock appreciation rights activity for the years ended December 31, 2013, 2012, and 2011 is presented below:
		2013						2012				2011
				Weighted-Average Exercise Price						Weighted-Average Exercise Price				Weighted-Average Exercise Price
		Shares						Shares				Shares
	Outstanding at beginning of period	14,846,994		$	6.01			12,566,199		$	5.64	12,779,282		$	2.65
	Granted	4,937,575		$	4.11			4,978,750		$	6	5,601,792		$	7.74
	Exercised	(1,466,025	)	$	3.66			(1,304,050	)	$	1.54	(5,479,250	)	$	0.92
	Forfeited or expired	(1,427,125	)	$	5.51			(1,393,905	)	$	7.14	(335,625	)	$	3.4
	Outstanding at end of period	16,891,419		$	5.69			14,846,994		$	6.01	12,566,199		$	5.64
	Exercisable at end of the year	9,983,743		$	5.96			8,683,622		$	5.97	6,915,471		$	4.97
	A summary of the Company’s non-vested options and stock appreciation rights as of December 31, 2013, 2012, and 2011 is presented below:
	Non-vested Options	2013		2012			2011
	Non-vested at beginning of period	6,163,372		5,650,782			5,215,532
	Granted	4,937,575		4,978,750			5,601,792
	Vested	(3,133,700	)	(3,405,434	)		(4,832,417	)
	Forfeited	(1,059,771	)	(1,060,726	)		(334,125	)
	Non-vested at end of period	6,907,476		6,163,372			5,650,782
	Total unrecognized compensation cost related to the non-vested options was $14.1 million, $12.6 million, and $9.2 million as of December 31, 2013, 2012, and 2011, respectively. The cost at December 31, 2013 is expected to be recognized over a weighted-average period of 1.77 years. At December 31, 2013, the aggregate intrinsic value for the outstanding options was $29.7 million; and the weighted average remaining contract life was 5.88 years.
	The assumptions used in the fair value method calculations for the years ended December 31, 2013, 2012, and 2011 are disclosed in the following table:
			Year Ended December 31,
			2013	2012		2011
	Weighted average fair value per option granted during the period (1)		$2.52	$3.72		$4.28
	Assumptions (2) :
	Weighted average stock price volatility (3)		80.61%	82.64%		64.29%
	Weighted average risk free rate of return		0.78%	0.77%		2.04%
	Weighted average estimated forfeiture rate (4)		2.45%	—%		—%
	Weighted average expected term		4.65 years	4.51 years		6.36 years
	(1)	Calculated using the Black-Scholes fair value based method for service and performance based grants and the Lattice Model for market based grants.
	(2)	The Company has not paid cash dividends on its common stock.
	(3)	The volatility assumption was estimated based upon a blended calculation of historical volatility and implied volatility over the life of the awards.
	(4)	For the years 2012 and 2011, the Company estimated forfeitures to be zero based on the majority of options being granted to executive officers who are less likely to forfeit shares.
	During 2013, the Company granted 182,994 fully vested shares of common stock to the Company’s board members as payment of board and committee meeting fees and chairperson retainers.
	A summary of the Company’s non-vested common shares granted under the Stock Incentive Plan as of December 31, 2013, 2012, and 2011 is presented below:
		2013						2012				2011
				Weighted-Average Share Price						Weighted-Average Share Price				Weighted-Average Share Price
	Non-vested Shares	Shares						Shares				Shares
	Non-vested at beginning of year	65,025		$	6.09			155,049		$	4.43	300,074		$	4.43
	Granted	210,494		$	4.66			69,791		$	4.29	40,305		$	5.45
	Vested	(248,019	)	$	4.75			(159,815	)	$	4.46	(185,330	)	$	0.47
	Non-vested at end of year	27,500		$	7.24			65,025		$	6.09	155,049		$	4.43
	Total unrecognized compensation cost related to the above non-vested shares amounted to $0.2 million, $0.4 million, and $0.8 million as of December 31, 2013, 2012, and 2011, respectively. The unrecognized compensation cost at December 31, 2013 is expected to be recognized over a weighted-average period of 2.9 years.

SHAREHOLDERS_EQUITY

SHAREHOLDERS' EQUITY	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
SHAREHOLDERS' EQUITY	'
	NOTE 10 - SHAREHOLDERS' EQUITY
	Common Stock
	During the years ended December 31, 2013, 2012, and 2011, the Company issued :
	•	182,994, 84,052, and 121,143 shares, respectively, of the Company’s common stock in connection with share-based compensation which had fully vested to certain senior management and officers of the Company.
	•	1,466,025, 1,438,275, and 6,293,107 shares, respectively, of the Company’s common stock upon the exercise of warrants and options for total proceeds of approximately $5.4 million, $2.3 million, and $7.6 million, respectively.
	During the year ended December 31, 2011, the Company issued 1,713,598 shares of common stock in open market transactions at an average price of $8.27 per share pursuant to an “At the Market” sales agreement (ATM) the Company had with its sales agent for total proceeds of approximately $13.9 million. Sales of shares of the Company's common stock by its sales agent have been made in privately negotiated transactions or in any method permitted by law deemed to be an “At The Market” offering as defined in Rule 415 promulgated under the Securities Act of 1933, as amended, at negotiated prices, at prices prevailing at the time of sale or at prices related to such prevailing market prices, including sales made directly on an exchange or sales made through a market maker other than on an exchange. The Company's sales agent has made all sales using commercially reasonable efforts consistent with its normal sales and trading practices on mutually agreed upon terms between the Company and its sales agent.
	On January 14, 2011, the Company issued 946,314 shares of common stock valued at approximately $7.5 million based on a closing stock price of $7.97 as consideration in the second closing of the PostRock assets acquisition.
	On April 13, 2011, the Company issued 6,635,478 shares of common stock valued at approximately $53.0 million based on a closing stock price of $7.99 as consideration in the closing of the acquisition of NGAS. In connection with the NGAS acquisition, the Company issued 350,626 shares of common stock valued at approximately $2.8 million to NGAS employees as change in control payments.
	On May 3, 2011, the Company issued 38,131,846 shares of common stock valued at approximately $282.2 million based on a closing stock price of $7.40 as consideration in the closing of the acquisition of NuLoch.
	On March 30, 2012, the Company issued 296,859 restricted shares of the Company’s common stock valued at approximately $1.9 million based on a price of $6.41 per share as partial consideration for the acquisition of the assets of Eagle Operating.
	On May 16, 2012, the Company issued 35,000,000 shares of the Company’s common stock in an underwritten public offering at a price of $4.50 per share for total proceeds of $157.5 million.  The net proceeds of the offering, after deducting underwriting discounts and commissions and offering expenses, were approximately $148.2 million.
	During the years ended December 31, 2013, 2012, and 2011 the Company issued 505,835, 3,188,036, and 582,127 shares of the Company’s common stock, respectively, upon exchange of exchangeable shares issued by MHR Exchangeco Corporation in connection with the Company’s acquisition of NuLoch Resources, Inc. in May 2011.
	On August 13, 2013 and August 20, 2012, the Company issued an aggregate of 221,170 and 199,055 shares, respectively, of the Company’s common stock as "safe harbor" and discretionary matching contributions to the Magnum Hunter Resources Corporation 401(k) Employee Stock Ownership Plan (the "KSOP" or the "Plan"). The Plan was established effective October 1, 2010 as a defined contribution plan. At the discretion of the Board of Directors, the Company may elect to contribute discretionary contributions to the Plan either as profit sharing contributions or as employee stock ownership plan contributions. It is the intent of the Company to review and make discretionary contributions to the Plan in the future, however, the Company has no further obligation to make future contributions to the Plan as of December 31, 2013, except for statutorily required "safe harbor" matching contributions.
	Unearned Common Stock in Magnum Hunter Resources Corporation 401(k) Employee Stock Ownership Plan
	On August 13, 2012, the Company rescinded the loan of 153,300 Magnum Hunter common shares to the Company's KSOP and the common shares were returned to the Company and held in treasury at cost of $3.94 per share. The loan was rescinded to correct a mutual mistake by the parties in connection with the Company’s original acquisition of the shares through open market purchases. The Company has agreed that 153,300 shares of the Company’s common stock will either be (i) offered for sale to the participants in the Plan at a price not to exceed the lesser of $3.94 per share (the basis of these treasury shares) or the fair market value of the shares on the date of the sale, or (ii) contributed to the Plan as one or more discretionary matching contributions.  Such sale or contribution shall be made at such time or times as determined by the trustee of the Plan, except to the extent that the Company elects prior to that time to contribute all or a part of such shares as a discretionary matching contribution.
	Exchangeable Common Stock
	On May 3, 2011, in connection with the acquisition of NuLoch, the Company issued 4,275,998 exchangeable shares of MHR Exchangeco Corporation, which are exchangeable for shares of the Company at a one for one ratio. The shares of MHR Exchangeco Corporation were valued at approximately $31.6 million. Each exchangeable share was exchangeable for one share of the Company's common stock at any time after issuance at the option of the holder and was redeemable at the option of the Company, through Exchangeco, after one year or upon the earlier of certain specified events. During the year ended December 31, 2013, 2012, and 2011, 505,835, 3,188,036, and 582,127, respectively, of the exchangeable shares were exchanged for common shares of the Company. As of December 31, 2013, there were no exchangeable shares outstanding.
	Common Stock Warrants
	During 2006, the Company issued 871,500 warrants to purchase an equal number of shares of the Company’s common stock at an exercise price of $3.00 per share in conjunction with private placement sales of common stock.  The warrants had a term of five years from the date of issuance.  The Company also issued 326,812 warrants to purchase an equal number of shares of the Company’s common stock at an exercise price of $3.00 per share along with a cash payment for commission fees.
	In association with common stock sales on November 5, 2009, the Company issued 457,982 common stock warrants. Each warrant issued to a purchaser had a term of 3 years and (i) was exercisable for one share of the Company's common stock at any time after the shares of common stock underlying the warrant are registered with the SEC for resale pursuant to an effective registration statement, which was June 12, 2010, (ii) had a cash exercise price of $2.50 per share of the Company's common stock, and (iii) upon notice to the holder of the warrant, was redeemable by the Company for $0.01 per share of the Company's common stock underlying the warrant if (a) the registration statement as filed with the SEC is effective and (b) the average trading price of the Company's common stock as traded and quoted on the NYSE Amex equals or exceeds $3.75 per share for at least 20 days in any period of 30 consecutive days.
	On November 16, 2009, the Company issued 1,280,744 common stock warrants. The warrants, which represent the right to acquire an aggregate of up to 1,280,744 common shares, were exercisable at any time on or after May 17, 2010 and had a term of 3 years, at an exercise price of $2.50 per share, which was 145% of the closing price of the Company's common shares on the NYSE Amex on November 11, 2009. These warrants were exercised during the years 2010, 2011, 2012.
	On April 13, 2011, at the time of the NGAS acquisition, NGAS had 4,609,038 warrants outstanding which were converted, based on the exchange ratio of 0.0846, to 389,924 warrants exercisable for Magnum Hunter common stock. The warrants had a cash-out option, which remained available to the holder for 30 days from the date of the acquisition, based on fair market value of the warrants at April 13, 2011. The Company paid cash of $1.0 million upon exercise of the cash-out option on the warrants exercisable for 251,536 shares of the Company’s common stock. At December 31, 2013, common stock warrants exercisable for 138,388 shares of the Company’s common stock were outstanding. The warrants consist of 97,780 warrants with an exercise price of $15.13 which expire February 13, 2014 and 40,608 warrants with an exercise price of $19.04 which expire November 17, 2014.
	On August 13, 2011, the Company declared a dividend to be paid in the form of one common stock warrant for every ten shares held by holders of record of the Company's common stock and exchangeable shares of MHR Exchangeco Corporation on August 31, 2011. The Company issued 12,875,093 common stock warrants to common stock holders and 378,174 warrants to holders of MHR Exchangeco Corporation exchangeable shares. Each warrant entitled the holder to purchase one share of the Company’s common stock for an initial exercise price of $10.50 and expired on October 14, 2013. The fair market value of the warrants was $6.9 million. The warrants were accounted for in additional paid-in capital rather than as a reduction of retained earnings because the Company has an accumulated deficit position.
	On August 26, 2013, the Company declared a dividend on its outstanding shares of common stock in the form of 17,030,622 warrants to purchase shares of the Company's common stock at $8.50 per share with such warrants having a fair value of $21.6 million as of the declaration date of August 26, 2013. The warrants were issued on October 15, 2013 to shareholders of record on September 16, 2013. Each shareholder of record received one warrant for every ten shares owned as of the record date (with the number of warrants rounded down to the nearest whole number). Each warrant entitles the holder to purchase one share of the Company's common stock at an exercise price of $8.50 per share, subject to certain anti-dilution adjustments, and will expire on April 15, 2016. The warrants will become exercisable on the later of September 1, 2014 or the date that a registration statement has been filed with and declared effective by the SEC with respect to the issuance of the common stock underlying the warrants. The warrants will be subject to redemption at the option of the Company at $0.001 per warrant upon not less than thirty days’ notice to the holders.
	During the year ended December 31, 2011, 771,812 of the Company's $3.00 common stock warrants and 42,045 of the Company's $2.50 common stock warrants were exercised for total combined proceeds of approximately $2.4 million, and 15,000 of the Company's $3.00 common stock warrants expired.
	During the year ended December 31, 2012, 48 of the Company's $10.50 common stock warrants and 134,177 of the Company's $2.50 common stock warrants were exercised for total combined proceeds of approximately $328,000, and 15,330 of the Company's $10.50 common stock warrants were canceled upon the rescission of the 153,300 Magnum Hunter common shares loaned to the Company's KSOP.
	During the year ended December 31, 2013, 13,237,889 of the Company's $10.50 common stock warrants expired.
	A summary of warrant activity for the years ended December 31, 2013, 2012, and 2011 is presented below:
		2013						2012					2011
				Weighted -						Weighted -					Weighted -
				Average						Average					Average
		Shares		Exercise Price				Shares		Exercise Price			Shares		Exercise Price
	Outstanding at beginning of year	13,376,277		$	10.56			13,525,832		$	10.48		963,034		$	2.91
	Granted	17,030,622		$	8.5			—		$	—		13,391,655		$	10.56
	Exercised, forfeited, or expired	(13,237,889	)	$	10.5			(149,555	)	$	3.32		(828,857	)	$	2.97
	Outstanding at end of year	17,169,010		$	8.56			13,376,277		$	10.56		13,525,832		$	10.48
	Exercisable at end of year	17,169,010		$	8.56			13,376,277		$	10.56		13,525,832		$	10.48
	At December 31, 2013, the warrants had no aggregate fair value; and the weighted average remaining contract life was 0.8 years.
	Series D Preferred Stock
	During the year ended December 31, 2011, the Company sold 1,437,558 shares of our 8.0% Series D Cumulative Preferred Stock, par value $0.01 per share and liquidation preference of $50.00 per share, of which 400,000 were sold in an underwritten offering and 1,037,558 were sold under the ATM sales agreement, for net proceeds of $65.0 million. The Series D Preferred Stock cannot be converted into common stock of the Company but may be redeemed by the Company, at the Company’s option, on or after March 14, 2014 for par value or $50.00 per share or in certain circumstances prior to such date as a result of a change in control of the Company. Dividends accrue and are payable monthly on the Series D Preferred Stock at a fixed rate of 8.0% per annum of the $50.00 per share liquidation preference.
	During the year ended December 31, 2012, the Company issued an aggregate of 2,771,263 shares of our 8.0% Series D Cumulative Preferred Stock for cumulative net proceeds of approximately $122.5 million, which included various offering expenses of approximately $3.1 million. The 2,771,263 shares of our 8.0% Series D Cumulative Preferred Stock issued during the year ended December 31, 2012 included (i) 1,721,263 shares issued under an ATM sales agreement for net proceeds of approximately $77.9 million, which included approximately $1.5 million of offering and underwriting fees and (ii) 1,050,000 shares issued pursuant to an underwritten public offering on September 7, 2012 at a price of $44.00 per share for net proceeds of approximately $44.6 million, which included approximately $1.6 million of underwriting discounts, commissions and offering expenses.
	During the year ended December 31, 2013, the Company issued under an ATM sales agreement 216,068 shares of its Series D Preferred Stock for net proceeds of approximately $9.6 million, which included sales agent commissions and other issuance costs of approximately $1.2 million.
	Series E Preferred Stock
	Each share of Series E Preferred Stock, par value $0.01 per share, has a stated liquidation preference of $25,000 and a dividend rate of 8.0% per annum (based on stated liquidation preference), is convertible at the option of the holder into a number of shares of the Company’s common stock equal to the stated liquidation preference (plus accrued and unpaid dividends) divided by a conversion price of $8.50 per share (subject to anti-dilution adjustments in the case of stock dividends, stock splits and combinations of shares), and is redeemable by the Company under certain circumstances.  The Series E Preferred Stock is junior to the Company’s 10.25% Series C Cumulative Perpetual Preferred Stock and 8.0% Series D Cumulative Preferred Stock in respect of dividends and distributions upon liquidation.  Each Depositary Share is a 1/1000th interest in a share of Series E Preferred Stock.  Accordingly, the Depositary Shares have a stated liquidation preference of $25.00 per share and a dividend rate of 8.0% per annum (based on stated liquidation preference), are similarly convertible at the option of the holder into a number of shares of the Company’s common stock equal to the stated liquidation preference (plus accrued and unpaid dividends) divided by a conversion price of $8.50 per share (subject to corresponding anti-dilution adjustments), and are redeemable by the Company under certain circumstances.
	In November 2012, the Company issued 2,774,850 Depositary Shares, each representing a 1/1,000th interest in a share of the Company’s 8% Series E Cumulative Convertible Preferred Stock, liquidation preference $25,000 per share, to the shareholders of Virco as partial consideration for the Company’s purchase of 100% of the outstanding stock of Virco. The Company also issued 70,000 Depositary Shares into an escrow account which were returned and held in treasury at cost of $1.8 million upon an indemnification settlement in favor of the Company.
	In December 2012, the Company sold in a public offering an aggregate of 1,000,000 Depositary Shares, each representing a 1/1,000th interest in a share of the Company’s 8% Series E Cumulative Convertible Preferred Stock, liquidation preference $25,000 per share.  The Depositary Shares were sold to the public at a price of $23.50 per Depositary Share, and the net proceeds to the Company were $22.44 per Depositary Share after deducting underwriting commissions, but before deducting expenses related to the offering.
	During the year ended December 31, 2013, the Company issued under an ATM sales agreement an aggregate of 27,906 Depositary Shares, each representing a 1/1,000th interest in a share of the Company’s Series E Preferred Stock. The Depositary Shares were sold to the public at an average price of $24.24 per Depositary Share, and net proceeds to the Company were $590,000 after deducting sales agent commissions and other issuance costs.
	Non-controlling Interests
	During the year ended December 31, 2012, the Company purchased outstanding non-controlling interest in a subsidiary which the Company did not previously own.  The Company acquired the non-controlling interest valued at $497,000 based on fair value at the date of acquisition.
	In connection with a Williston Basin acquisition in 2008, the Company entered into equity participation agreements with certain of its lenders pursuant to which the Company agreed to pay to the lenders an aggregate of 12.5% of all distributions paid to the owners of PRC Williston, which equity participation agreements, for accounting purposes, are treated as non-controlling interests in PRC Williston, and consequently, PRC Williston is treated as a majority owned subsidiary of the Company and is consolidated by the Company. The equity participation agreements had a fair value of $3.4 million upon issuance and were accounted for as a non-controlling interest in PRC Williston.
	On April 2, 2012, Eureka Hunter Holdings, a majority owned subsidiary, issued 622,641 Class A Common Units representing membership interests in Eureka Hunter Holdings, with a value of $12.5 million, as partial consideration for the assets acquired from TransTex.  The value of the units transferred as partial consideration for the acquisition was determined utilizing a discounted future cash flow analysis. The carrying value of the Eureka Hunter Holdings Class A Common Units held by third parties is classified as non-controlling interest.
	A summary of non-controlling interests in the Company for the years ended December 31, 2013, 2012, and 2011 is presented below:
		Year Ended December 31,
		2013				2012				2011
		(in thousands)
	Non-controlling interest at beginning of period	$	10,139			$	2,196			$	1,450
	Non-controlling interests acquired through acquisition of NGAS	—				—				497
	Purchase of outstanding non-controlling interests	—				(497		)		—
	Issuance of shares of Eureka Hunter Holdings, LLC Common Units	—				12,453				—
	Income (loss) attributable to non-controlling interest	(988		)		(4,013		)		249
	Other	(1		)		—				—
	Non-controlling interest at end of period	$	9,150			$	10,139			$	2,196
	Preferred Dividends Paid
A summary of dividends paid by the Company for the years ended December 31, 2013, 2012, and 2011 is presented below:
	Year Ended December 31,
	2013				2012				2011
	(in thousands)
Dividend on Eureka Hunter Holdings, LLC Series A Preferred Units	$	(14,323	)		$	(8,090	)		$	—
Dividend on Series C Preferred Stock	(10,248		)		(10,248		)		(10,248		)
Dividend on Series D Preferred Stock	(17,655		)		(11,699		)		(3,759		)
Dividend on Series E Preferred Stock	(7,561		)		(894		)		—
Total dividends on Preferred Stock	$	(49,787	)		$	(30,931	)		$	(14,007	)
Accretion of the difference between the carrying value and the redemption value of the Eureka Hunter Holdings, Series A Preferred Units of $6.9 million for the year ended December 31, 2013, $3.8 million for the year ended December 31, 2012, and none for the year ended December 31, 2011, was included in dividends on preferred stock.

REEDEMABLE_PREFERRED_STOCK

REEDEMABLE PREFERRED STOCK	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
REEDEMABLE PREFERRED STOCK	'
	NOTE 11 - REDEEMABLE PREFERRED STOCK
	Series C Preferred Stock
	On December 13, 2009, the Company sold 214,950 shares of its 10.25% Series C Cumulative Perpetual Preferred Stock, par value $0.01 per share and liquidation preference $25.00 per share (the “Series C Preferred Stock”), for net proceeds of $5.1 million. The Series C Preferred Stock cannot be converted into common stock of the Company, but may be redeemed by the Company, at the Company’s option, on or after December 14, 2011 for par value or $25.00 per share.  In the event of a change of control of the Company, the Series C Preferred Stock will be redeemable by the holders at $25.00 per share, except in certain circumstances when the acquirer is considered a qualifying public company. The Series C Preferred Stock is recorded as temporary equity because a forced redemption, upon certain circumstances as a result of a change in control of the Company, is outside the Company’s control. Dividends accrue and are payable monthly on the Series C Preferred Stock at a fixed rate of 10.25% per annum of the $25.00 per share liquidation preference.
	During the year ended December 31, 2010, the Company sold 2,594,506 shares of the Series C Preferred Stock under its ATM sales agreement for net proceeds of $63.4 million.
	During the year ended December 31, 2011, the Company sold 1,190,544 shares of its 10.25% Series C Cumulative Perpetual Preferred Stock under its ATM sales agreement for net proceeds of $29.1 million. The sales during the year ended December 31, 2011 have fully subscribed the authorized 4,000,000 shares of Series C Preferred Stock.
	Eureka Hunter Holdings, LLC Series A Preferred Units
	On March 21, 2012, Eureka Hunter Holdings entered into a Series A Convertible Preferred Unit Purchase Agreement (the “Unit Purchase Agreement”) with Magnum Hunter and Ridgeline Midstream Holdings, LLC (“Ridgeline”), an affiliate of ArcLight Capital Partners, LLC. Pursuant to this Unit Purchase Agreement, Ridgeline committed, subject to certain conditions, to purchase up to $200 million of Series A Convertible Preferred Units representing membership interests of Eureka Hunter Holdings (the “Series A Preferred Units”).
	During the years ended December 31, 2013 and December 31, 2012, Eureka Hunter Holdings issued 1,800,000 and 7,590,000, Series A Preferred Units, respectively, to Ridgeline for net proceeds of $35.3 million and $148.6 million, respectively, net of transaction costs.  The Series A Preferred Units outstanding at December 31, 2013 represented 41.7% of the ownership of Eureka Hunter Holdings on a basis as converted to Class A Common Units of Eureka Hunter Holdings and represent non-controlling interests in the form of redeemable preferred stock of a subsidiary in consolidation of the Company.  Eureka Hunter Holdings pays cumulative distributions quarterly on the Series A Preferred Units at a fixed rate of 8% per annum of the initial liquidation preference.  The distribution rate is increased to 10% if any distribution is not paid when due.  The board of directors of Eureka Hunter Holdings may elect to pay up to 75% of the distributions owed for the period from March 21, 2012 through March 31, 2013 in the form of “paid-in-kind” units and may elect to pay up to 50% of the distributions owed for the period from April 1, 2013 through March 31, 2014 in such units.  The Series A Preferred Units can be converted into Class A Common Units of Eureka Hunter Holdings upon demand by Ridgeline at any time or by Eureka Hunter Holdings upon the consummation of a qualified initial public offering, provided that Eureka Hunter Holdings converts no less than 50% of the Series A Preferred Units into Class A Common Units at that time.  The conversion rate is 1:1, which may be adjusted from time to time based upon certain anti-dilution and other provisions.  Eureka Hunter Holdings can redeem all outstanding Series A Preferred Units at their liquidation preference, which involves a specified IRR hurdle, any time after March 21, 2017.  Holders of the Series A Preferred Units can force redemption of all outstanding Series A Preferred Units any time after March 21, 2020, at a redemption rate equal to the higher of the as-converted value and a specified internal investment rate of return calculation.  The Series A Preferred Units are recorded as temporary equity because a forced redemption by the holders of the preferred units is outside the control of Eureka Hunter Holdings.
	The Company has evaluated the Series A Preferred Units and determined that they should be considered a “debt host” and not an “equity host”. This evaluation is necessary to determine if any embedded features require bifurcation and, therefore, would be required to be accounted for separately as a derivative liability. The Company's analysis followed the “whole instrument approach,” which compares an individual feature against the entire preferred instrument that includes that feature. The Company's analysis was based on a consideration of the economic characteristics and risks of the preferred unit and, more specifically, evaluated all of the stated and implied substantive terms and features of such unit, including (1) whether the preferred unit included redemption features; (2) how and when any redemption features could be exercised; (3) whether the holders of preferred units were entitled to dividends; (4) the voting rights of the preferred unit; and (5) the existence and nature of any conversion rights. As a result of the Company's determination that the preferred unit is a “debt host,” the Company determined that the embedded conversion option, redemption options and other features of the preferred units do require bifurcation and separate accounting as embedded derivatives. The fair value of the embedded features were determined at the issuance dates which were bifurcated from the issuance values of the Series A Preferred Units and presented in long term liabilities. The fair value of this embedded feature was determined to be $75.9 million and $43.5 million in the aggregate at December 31, 2013 and 2012, respectively. See "Note 3 - Fair Value of Financial Instruments".
	During the year ended December 31, 2013, the Company paid cash distributions of $5.2 million and accrued distributions of $3.9 million not yet paid, to the holder of the Company's Series A Preferred Units. During such year, distributions in the amount of $8.2 million were paid-in-kind to the holder of the Series A Preferred Units and the Company issued 412,157 Series A Preferred Units as payment. At December 31, 2013, 9,885,048 shares of Series A Preferred Units were outstanding.

INCOME_TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
INCOME TAXES	'
	NOTE 12 - INCOME TAXES
	The total provision for income taxes applicable to continuing operations consists of the following:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Deferred income tax benefit
	Federal	$	(63,629	)	$	(15,109	)	$	(1,025	)
	State	(6,668		)	(4,203		)	(1,837		)
	Total deferred tax benefit	$	(70,297	)	$	(19,312	)	$	(2,862	)
	Total income tax benefit	$	(70,297	)	$	(19,312	)	$	(2,862	)
	At December 31, 2013, the Company has net operating loss carryforwards ("NOL's") available for U.S. federal income tax purposes of approximately $400 million, which expire in varying amounts during the tax years 2018 through 2033. In addition, the Company has NOL carryforwards related to its Canadian operations of approximately $66.4 million , which expire in varying amounts between years 2015 through 2033. The deferred tax asset recorded for the U.S. NOL does not include $22.4 million of deductions for excess stock-based compensation (tax effected $8.3 million). The Company will recognize the NOL tax assets associated with excess stock-based compensation tax deductions only when all other components of the NOL tax assets have been fully utilized and a cash tax benefit is realized. Upon realization, the excess stock-based compensation deduction will reduce taxes payable and will be credited directly to equity.
	At December 31, 2013, the Company was not under examination by any federal or state taxing jurisdiction, nor had the Company been contacted by any examining agency.
	The Company has approximately $2.8 million (tax effected $1.1 million) of depletion carryover which has no expiration.
	The Company has no unremitted earnings in Canada.
	The Company has recorded a valuation allowance of $150.5 million against the net deferred tax assets of the Company at December 31, 2013. The Company is uncertain on a more likely than not basis that the NOL and other deferred tax assets will be utilized in the future. Management evaluated all available positive and negative evidence in making this assessment. The assessment included objectively verifiable information such as historical operating results, future projections of operating results, future reversals of existing taxable temporary differences and anticipated capital expenditures. Management placed a significant amount of weight on the historical results.
	The following is a reconciliation of the reported amount of income tax expense (benefit) attributable to continuing operations for the years ended December 31, 2013, 2012, and 2011 to the amount of income tax expense that would result from applying domestic federal statutory tax rates to pretax income:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Income tax benefit at statutory U.S. rate	$	(96,022	)	$	(48,639	)	$	(20,887	)
	State income taxes (net of federal benefit)	(4,334		)	(2,732		)	(1,194		)
	Tax effect of permanent differences	750			(555		)	419
	Tax effect of loss attributable to non-controlled interest	346			797			—
	Tax benefit recognized as tax expense in discontinued operations	(13,879		)	—			—
	Change in valuation allowance	43,232			31,810			18,800
	Other	(390		)	7			—
	Total continuing operations	(70,297		)	(19,312		)	(2,862		)
	Discontinued operations	(3,336		)	(2,283		)	2,166
	Total tax benefit	$	(73,633	)	$	(21,595	)	$	(696	)
	Income (loss) before income taxes was as follows:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Domestic	$	(274,349	)	$	(138,968	)	$	(59,676	)
	Loss from continuing operations	(274,349		)	(138,968		)	(59,676		)
	Loss from discontinued operations	(75,838		)	(23,053		)	(17,432		)
	Gain on disposal of discontinued operations	53,389			3,706			—
	Loss before income tax	$	(296,798	)	$	(158,315	)	$	(77,108	)
	Deferred Tax Assets and Liabilities
	The tax effects of temporary differences that gave rise to the Company's deferred tax assets and liabilities are presented below:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Deferred tax assets:
	Net operating loss carry forwards	$	155,507		$	193,310		$	62,923
	Share-based compensation	10,156			7,950			10,247
	Depletion carryforwards	1,047			997			972
	Tax credits	53			53			26,340
	US investment in Canada	74,148			—			—
	Other	561			532			7,475
	Deferred tax liabilities:
	Property and equipment	(90,950		)	(206,650		)	(111,015		)
	Valuation allowance	(150,522		)	(70,450		)	(92,241		)
	Net deferred tax asset (liability)	$	—		$	(74,258	)	$	(95,299	)
	As of December 31, 2013 the Company provided for a liability of $3.9 million for unrecognized tax benefits related to various federal tax matters, which were netted against the Company's net operating loss. Settlement of the uncertain tax position is expected to occur in the next 12 months and will have no effect on income tax expense (benefit). The Company has elected to classify interest and penalties related to uncertain income tax positions in income tax expense. Due to available NOLs, as of December 31, 2013, the Company has accrued no amounts for potential payment of interest and penalties.
	Following is a reconciliation of the total amounts of unrecognized tax benefits during the years ended December 31, 2013, 2012 and 2011:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Unrecognized tax benefits at January 1	$	3,879		$	—		$	—
	Change in unrecognized tax benefits taken during a prior period	—			—			—
	Change in unrecognized tax benefits taken during the current period (netted against the US net operating loss)	—			3,879			—
	Decreases in unrecognized tax benefits from settlements with taxing authorities	—			—			—
Reductions to unrecognized tax benefits from lapse of statutes of limitations	—			—			—
Unrecognized tax benefits at December 31	$	3,879		$	3,879		$	—

MAJOR_CUSTOMERS

MAJOR CUSTOMERS	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
MAJOR CUSTOMERS	'
	NOTE 13 - MAJOR CUSTOMERS
	The Company's share of oil and gas production is sold to various purchasers who must be prequalified under the Company's credit risk policies and procedures. After giving effect to the Eagle Ford Hunter sale, the following purchasers individually accounted for ten percent or more of the Company's consolidated continuing oil and gas revenues in at least one of the three years ended December 31, 2013. The loss of any one significant purchaser could have a material, adverse effect on the ability of the Company to sell its oil and gas production. Although the Company is exposed to a concentration of credit risk, the Company believes that all of its purchasers are credit worthy.
	The table below provides the percentages of the Company's consolidated oil, NGL and gas revenues from continuing operations represented by its major purchasers during the periods presented:
		Year Ended December 31,
		2013		2012		2011
	Samson Resources Company	36	%	17	%	10	%
	Baytex Energy USA LTD	10	%	15	%	3	%
	Teneska Marketing Ventures	9	%	14	%	14	%
	South Jersey	5	%	14	%	10	%
	Plains Marketing, LP	4	%	11	%	16	%
	Clearfield Energy	1	%	7	%	16	%
	Ergon Oil	3	%	5	%	13	%

SUPPLEMENTAL_CASH_FLOW_INFORMA

SUPPLEMENTAL CASH FLOW INFORMATION (Notes)	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Elements [Abstract]	'
SUPPLEMENTAL CASH FLOW INFORMATION	'
	NOTE 14 - SUPPLEMENTAL CASH FLOW INFORMATION
	The following summarizes cash paid (received) for interest and income taxes, as well as non-cash investing transactions:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
	Cash paid for interest	$	70,366		$	40,069	$	7,952
	Cash paid for taxes	$	1,200		$	—	$	—
	Non-cash transactions
	Change in accrued capital expenditures - increase (decrease)	$	(65,634	)	$	34,621	$	81,136
	Eureka Hunter Holdings, LLC Series A convertible preferred unit dividends paid in kind	$	8,243		$	1,658	$	—
	Non-cash additions to asset retirement obligation	$	2,132		$	8,492	$	12,628
	Common stock issued for 401k matching contributions	$	1,192		$	874	$	—
	Preferred stock issued for acquisitions	$	—		$	64,968	$	—
	Eureka Hunter Holdings, LLC Class A common units issued for an acquisition	$	—		$	12,453	$	—
	Non-cash consideration received from sale of assets	$	42,300		$	7,120	$	—
	Common stock issued for acquisitions	$	—		$	1,902	$	345,537
	Debt assumed in acquisitions	$	—		$	—	$	71,895
	Exchangeable common stock issued for acquisition of NuLoch Resources	$	—		$	—	$	31,642
	Common stock issued for payment of services	$	—		$	—	$	779
	Dividends on MHR Exchangeco Corporation's exchangeable common stock in the form of 378,174 warrants with fair market value of $197 thousand	$	—		$	—	$	197
	The Company issued dividends on common stock in the form of 17,030,622 warrants and 12,875,093 warrants with fair value of $21.6 million and $6.7 during the years ended December 31, 2013 and 2012, respectively.

OTHER_INFORMATION

OTHER INFORMATION	12 Months Ended
	Dec. 31, 2013
Other Information	'
OTHER INFORMATION	'
	NOTE 15 - OTHER INFORMATION
	Quarterly Data (Unaudited)
	The following tables set forth unaudited summary financial results on a quarterly basis for the most recent two years.
		Quarter Ended
		March 31,			June 30,			September 30,			December 31,			Year Ended
		2013
		(in thousands)
	Total revenue	$	54,235		$	67,907		$	73,032		$	85,237		$	280,411
	Operating gain (loss) (1)	$	(40,009	)	$	(26,240	)	$	(92,676	)	$	(25,839	)	$	(184,764	)
	Income (loss) from continuing operations	$	(61,544	)	$	347		$	(132,598	)	$	(10,257	)	$	(204,052	)
	Income (loss) from discontinued operations, net of tax (2)	$	16,845		$	(7,746	)	$	(80,554	)	$	324		$	(71,131	)
	Gain (loss) on disposal of discontinued operations, net of tax (3)	$	—		$	172,452		$	(84,454	)	$	(35,979	)	$	52,019
	Net income (loss) attributable to Magnum Hunter Resources Corporation	$	(44,197	)	$	165,440		$	(296,882	)	$	(46,537	)	$	(222,176	)
	Net income (loss) attributable to common shareholders	$	(57,685	)	$	151,311		$	(311,299	)	$	(61,208	)	$	(278,881	)
	Basic and diluted income (loss) from continuing operations per common share	$	(0.36	)	$	0		$	(0.86	)	$	(0.06	)	$	(1.53	)
	Basic and diluted income (loss) per common share	$	(0.34	)	$	0.89		$	(1.83	)	$	(1.11	)	$	(1.64	)
		2012
	Total revenue	$	27,945		$	30,598		$	36,381		$	45,432		$	140,356
	Operating loss (4)	$	(15,698	)	$	(15,797	)	$	(8,898	)	$	(67,814	)	$	(108,207	)
	Loss from continuing operations	$	(22,533	)	$	(8,638	)	$	(31,313	)	$	(57,172	)	$	(119,656	)
	Income (loss) from discontinued operations, net of tax	$	5,723		$	(1,789	)	$	(1,102	)	$	(22,306	)	$	(19,474	)
	Gain (loss) on disposal of discontinued operations, net of tax	4,325			(2,101		)	—			185			2,409
	Net income (loss) attributable to Magnum Hunter Resources Corporation	$	(12,458	)	$	(12,577	)	$	(32,463	)	$	(75,210	)	$	(132,708	)
	Net loss attributable to common shareholders	$	(17,052	)	$	(20,843	)	$	(42,283	)	$	(87,236	)	$	(167,414	)
	Basic and diluted loss from continuing operations per common share	$	(0.17	)	$	(0.06	)	$	(0.19	)	$	(0.34	)	$	(0.96	)
	Basic and diluted income (loss) per common share	$	(0.13	)	$	(0.15	)	$	(0.25	)	$	(0.54	)	$	(1.07	)
	______________
	(1)	The quarter-ended September 30, 2013, loss from operations was primarily driven by the loss on the sale of certain properties in Burke County, North Dakota of $38.1 million, and exploration expense. Management reviews leasehold acreage on a quarterly basis. During the quarter-ended September 30, 2013, management determined a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return.
	(2)	The quarter-ended September 30, 2013, loss from discontinued operations was primarily driven by impairment expense of $72.5 million, as management determined a significant portion of the non-core acreage would not be utilized.
	(3)	The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".
	(4)	The quarter-ended December 31, 2012, loss from operations was primarily driven by exploration expense. During the quarter-ended December 31, 2012 management determined that a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return in 2013.
	Segment Reporting
	U.S. Upstream, Midstream and Oilfield Services represent the operating segments of the Company. As of December 31, 2013 the Canadian Upstream segment, comprised of the WHI Canada operations, was classified as assets held for sale and discontinued operations. The factors used to identify these reportable segments are based on the nature of the operations, nationality, operating strategies and management expertise involved in each. The Upstream segments are organized and operate to explore for and produce crude oil and natural gas within the geographic boundaries of the U.S. and Canada. The Midstream segment markets natural gas and operates a network of pipelines and compression stations that gather natural gas and NGL for transportation to market. The Oilfield Services segment provides drilling services to oil and natural gas exploration and production companies. Midstream and Oilfield Services customers are the Company's subsidiaries and other third-party oil and natural gas companies.
	The following tables set forth operating activities and capital expenditures by segment for the years ended, and segment assets as of December 31, 2013, 2012, and 2011.
		For the Year Ended December 31, 2013 (in thousands)
		U.S. Upstream				Canadian Upstream				Midstream				Oil Field Services			Corporate Unallocated			Intersegment Eliminations			Total
	Oil and gas sales	$	197,599			$	—			$	—			$	—		$	—		$	—		$	197,599
	Gas transportation, gathering and processing	2				—				69,306				—			—			(8,676		)	60,632
	Oil field services	23				—				—				21,525			—			(3,117		)	18,431
	Other revenue	3,747				—				—				2			—			—			3,749
	Total revenue	201,371				—				69,306				21,527			—			(11,793		)	280,411
	Lease operating expenses	62,675				—				—				—			—			(8,714		)	53,961
	Severance taxes and marketing	17,721				—				—				—			—			—			17,721
	Exploration	97,342				—				—				—			—			—			97,342
	Gas transportation, gathering and processing	2				—				52,097				—			—			—			52,099
	Oil field services	(10		)		—				—				17,914			—			(3,079		)	14,825
	Impairment of proved oil and gas properties	9,968				—				—				—			—			—			9,968
	Depreciation, depletion, and accretion	84,526				—				12,318				2,354			—			—			99,198
	Loss on sale of assets	44,642				—				8				4			—			—			44,654
	General and administrative	14,255				—				8,400				1,338			49,241			2,173			75,407
	Total expenses	331,121				—				72,823				21,610			49,241			(9,620		)	465,175
	Operating income (loss)	(129,750		)		—				(3,517		)		(83		)	(49,241		)	(2,173		)	(184,764		)
	Interest income	219				—				—				—			4,824			(4,823		)	220
	Interest expense	(7,208		)		—				(4,351		)		(507		)	(67,420		)	7,063			(72,423		)
	Loss on derivative contracts	(185		)		—				(17,742		)		—			(7,347		)	—			(25,274		)
	Other	(340		)		—				(265		)		—			8,497			—			7,892
	Total other income (expense)	(7,514		)		—				(22,358		)		(507		)	(61,446		)	2,240			(89,585		)
	Income (loss) from continuing operations before income tax	(137,264		)		—				(25,875		)		(590		)	(110,687		)	67			(274,349		)
	Income tax benefit (expense)	41,308				—				—				—			28,989			—			70,297
	Income (loss) from continuing operations	(95,956		)		—				(25,875		)		(590		)	(81,698		)	67			(204,052		)
	Income (loss) from discontinued operations	5,293				(76,355		)		—				—						(69		)	(71,131		)
	Gain (loss) on disposal of discontinued operations	125,871				(73,852		)		—				—			—			—			52,019
	Net income (loss)	35,208				(150,207		)		(25,875		)		(590		)	(81,698		)	(2		)	(223,164		)
Loss (income) attributable to non-controlling interest	—				—				—				—						988			988
Net income (loss) attributable to Magnum Hunter Resources Corporation	$	35,208			$	(150,207	)		$	(25,875	)		$	(590	)	$	(81,698	)	$	986		$	(222,176	)
Dividends on preferred stock	—				—				(21,241		)		—			(35,464		)	—			(56,705		)
Net income (loss) attributable to common shareholders	$	35,208			$	(150,207	)		$	(47,116	)		$	(590	)	$	(117,162	)	$	986		$	(278,881	)
Total segment assets	$	1,373,041			$	68,367			$	296,739			$	44,193		$	77,684		$	(3,373	)	$	1,856,651
Segment capital expenditures	$	489,702			$	31,025			$	87,048			$	22,699		$	1,037		$	—		$	631,511
	For the Year Ended December 31, 2012 (in thousands)
	U.S. Upstream				Canadian Upstream				Midstream				Oil Field Services			Corporate Unallocated			Intersegment Eliminations			Total
Oil and gas sales	$	114,659			$	—			$	—			$	—		$	—		$	—		$	114,659
Gas transportation, gathering and processing	—				—				15,469				—			—			(2,429		)	13,040
Oil field services	—				—				—				13,552			—			(1,219		)	12,333
Other revenue	99				—				223				—			—			2			324
Total revenue	114,758				—				15,692				13,552			—			(3,646		)	140,356
Lease operating expenses	30,429				—				—				—			—			(3,590		)	26,839
Severance taxes and marketing	7,854				—				—				—			—			—			7,854
Exploration	78,221				—				—				—			—			—			78,221
Gas transportation, gathering and processing	—				—				7,908				—			—			120			8,028
Oil field services	—				—				—				10,420			—			(383		)	10,037
Impairment of proved oil and gas properties	3,772				—				—				—			—			—			3,772
Depreciation, depletion, and accretion	52,332				—				5,963				967			—			468			59,730
Loss (gain) on sale of assets	278				—				(250		)		600			—			—			628
General and administrative	21,789				—				3,798				418			27,137			312			53,454
Total expenses	194,675				—				17,419				12,405			27,137			(3,073		)	248,563
Operating income (loss)	(79,917		)		—				(1,727		)		1,147			(27,137		)	(573		)	(108,207		)
Interest income	197				—				—				—			3,483			(3,481		)	199
Interest expense	(13,053		)		—				(758		)		(327		)	(41,022		)	3,544			(51,616		)
Loss on derivative contracts	129				—				8,692				—			13,418			—			22,239
Other	(882		)		—				(546		)		(155		)	—			—			(1,583		)
Total other income (expense)	(13,609		)		—				7,388				(482		)	(24,121		)	63			(30,761		)
Income (loss) from continuing operations before income tax	(93,526		)		—				5,661				665			(51,258		)	(510		)	(138,968		)
Income tax benefit (expense)	19,312				—				—				—			—			—			19,312
Income (loss) from continuing operations	(74,214		)		—				5,661				665			(51,258		)	(510		)	(119,656		)
Income (loss) from discontinued operations	6,661				(25,021		)		—				230			—			(1,344		)	(19,474		)
Gain on disposal of discontinued operations	2,409				—				—				—			—			—			2,409
Net income (loss)	(65,144		)		(25,021		)		5,661				895			(51,258		)	(1,854		)	(136,721		)
Net income (loss) attributable to non-controlling interest	4,173				—				(160		)		—			—			—			4,013
Net income (loss) attributable to Magnum Hunter Resources Corporation	(60,971		)		(25,021		)		5,501				895			(51,258		)	(1,854		)	(132,708		)
Dividends on preferred stock	—				—				(11,864		)		—			(22,842		)	—			(34,706		)
Net income (loss) attributable to common shareholders	$	(60,971	)		$	(25,021	)		$	(6,363	)		$	895		$	(74,100	)	$	(1,854	)	$	(167,414	)
Total segment assets	$	1,602,022			$	392,918			$	245,207			$	23,810		$	93,612		$	(158,937	)	$	2,198,632
Segment capital expenditures	$	417,431			$	84,536			$	57,010			$	8,828		$	805		$	—		$	568,610
	For the Year Ended December 31, 2011(in thousands)
	U.S. Upstream				Canadian Upstream				Midstream				Oil Field Services			Corporate Unallocated			Intersegment Eliminations			Total
Oil and gas sales	$	58,726			$	—			$	—			$	—		$	—		$	—		$	58,726
Gas transportation, gathering and processing	—				—				1,978				—			—			(1,484		)	494
Oil field services	—				—				—				9,417			—			(2,268		)	7,149
Other revenue	65				—				12				9			—			—			86
Total revenue	58,791				—				1,990				9,426			—			(3,752		)	66,455
Lease operating expenses	17,194				—				—				—			—			(2,196		)	14,998
Severance taxes and marketing	5,341				—				—				—			—			—			5,341
Exploration	2,605				—				—				—			—			—			2,605
Gas transportation, gathering and processing	—				—				373				—			—			—			373
Oil field services	—				—				—				8,315			—			(1,556		)	6,759
Impairment of proved oil and gas properties	—				—				—				—			—			—			—
Depreciation, depletion, and accretion	20,913				—				1,789				544			—			—			23,246
Loss (gain) on sale of assets	861				—				(500		)		—			—			—			361
General and administrative	2,255				—				850				461			50,794			—			54,360
Total expenses	49,169				—				2,512				9,320			50,794			(3,752		)	108,043
Operating income (loss)	9,622				—				(522		)		106			(50,794		)	—			(41,588		)
Interest income	6				—				—				—			4						10
Interest expense	(2,071		)		—				(1,673		)		(183		)	(9,879		)	2,054			(11,752		)
Gain (loss) on derivative contracts	—				—				—				—			(6,346		)	—			(6,346		)
Other	—				—				—				—			—			—			—
Total other expense	(2,065		)		—				(1,673		)		(183		)	(16,221		)	2,054			(18,088		)
Income (loss) from continuing operations before income tax	7,557				—				(2,195		)		(77		)	(67,015		)	2,054			(59,676		)
Income tax benefit	1,637				697				—				1,042			—			(514		)	2,862
Income (loss) from continuing operations	9,194				697				(2,195		)		965			(67,015		)	1,540			(56,814		)
Income (loss) from discontinued operations	(21,848		)		1,855				—				1,935			—			(1,540		)	(19,598		)
Gain on disposal of discontinued operations	—				—				—				—			—			—			—
Net income (loss)	(12,654		)		2,552				(2,195		)		2,900			(67,015		)	—			(76,412		)
Net loss attributable to non-controlling interest	(249		)		—				—				—			—			—			(249		)
Net income (loss) attributable to Magnum Hunter Resources Corporation	(12,903		)		2,552				(2,195		)		2,900			(67,015		)	—			(76,661		)
Dividends on preferred stock	—				—				—				—			(14,007		)	—			(14,007		)
Net income (loss) attributable to common shareholders	(12,903		)		2,552				(2,195		)		2,900			(81,022		)	—			(90,668		)
Total segment assets	$	797,674			$	349,410			$	83,847			$	17,045		$	47,839		$	(127,055	)	$	1,168,760
Segment capital expenditures	$	202,818			$	18,493			$	54,748			$	6,494		$	9,389		$	—		$	291,942
Supplemental Oil and Gas Disclosures (Unaudited)
The following table sets forth the costs incurred in oil and gas property acquisition, exploration, and development activities (in thousands):
	For the Year Ended December 31,
	2013				2012				2011
Purchase of non-producing leases	$	149,592			$	414,037			$	397,947
Purchase of producing properties	1,358				159,290				226,634
Exploration costs	11,531				165,789				112,606
Development costs	273,944				262,486				101,151
Asset retirement obligation	2,186				407				5,390
	$	438,611			$	1,002,009			$	843,728
Oil and Gas Reserve Information
Proved oil and gas reserve quantities are based on estimates prepared by Magnum Hunter’s third party reservoir engineering firms Cawley, Gillespie, & Associates, Inc. in 2013, and Cawley, Gillespie, & Associates, Inc. and AJM Deloitte in 2012 and 2011. There are numerous uncertainties inherent in estimating quantities of proved reserves and projecting future rates of production and timing of development expenditures. The following reserve data only represent estimates and should not be construed as being exact.
Total Proved Reserves		Crude Oil  and Liquids			Natural Gas
		(MBbl)			(MMcf)
Balance December 31, 2010		6,824			39,452
Revisions of previous estimates		6,937			40,494
Purchases of reserves in place		6,345			43,757
Extensions, discoveries, and other additions		2,687			22,399
Sales of reserves in place		-215			-11
Production		-869			-6,854
Balance December 31, 2011		21,709			139,237
Revisions of previous estimates		12,568			25,644
Purchases of reserves in place		10,613			12,082
Extensions, discoveries, and other additions		3,415			544
Sales of reserves in place		-10			-63
Production		-2,343			-14,824
Balance December 31, 2012		45,952			162,620
Extensions, discoveries and other additions		648			1,285
Revisions of previous estimates		6,148			100,456
Purchases of reserves in place		—			88
Sales of reserves in place		-15,204			-4,185
Production		-2,787			-13,482
Balance December 31, 2013		34,757			246,782
Developed reserves, included above:
December 31, 2011		9,179			90,198
December 31, 2012		22,617			125,526
December 31, 2013		19,075			176,585
Proved undeveloped reserves, included above:
31-Dec-11		12,531			49,039
31-Dec-12		23,335			37,094
31-Dec-13		15,682			70,197
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves
The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves and the changes in standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves were prepared in accordance with provisions of ASC 932, Extractive Activities - Oil and Gas. Future cash inflows at December 31, 2013, 2012, and 2011 were computed by applying the unweighted, arithmetic average of the closing price on the first day of each month for the 12-month period prior to December 31, 2013, 2012, and 2011 to estimated future production. Future production and development costs are computed by estimating the expenditures to be incurred in developing and producing the proved oil and natural gas reserves at year-end, based on year-end costs and assuming continuation of existing economic conditions.
Future income tax expenses are calculated by applying appropriate year-end tax rates to future pretax net cash flows relating to proved oil and natural gas reserves, less the tax basis of properties involved. Future income tax expenses give effect to permanent differences, tax credits and loss carry forwards relating to the proved oil and natural gas reserves. Future net cash flows are discounted at a rate of 10% annually to derive the standardized measure of discounted future net cash flows. This calculation procedure does not necessarily result in an estimate of the fair market value of the Company's oil and natural gas properties.
The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:
		Years Ended December 31,
		2013				2012				2011
		(in thousands)
Future cash inflows		$	3,711,260			$	4,248,384			$	2,409,249
Future production costs		(1,423,306		)		(1,520,260		)		(765,048		)
Future development costs		(421,797		)		(603,809		)		(330,007		)
Future income tax expense		(149,367		)		(230,500		)		(253,721		)
Future net cash flows		1,716,790				1,893,815				1,060,473
10% annual discount for estimated timing of cash flows		(872,280		)		(1,046,162		)		(586,077		)
Standardized measure of discounted future net cash flows		$	844,510			$	847,653			$	474,396
Future cash flows as shown above were reported without consideration for the effects of commodity derivative transactions outstanding at each period end.
Changes in Standardized Measure of Discounted Future Net Cash Flows
The changes in the standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:
		Years Ended December 31,
		2013				2012				2011
		(in thousands)
Balance, beginning of period		$	847,653			$	474,396			$	127,959
Net changes in prices and production costs		(7,355		)		13,647				49,498
Changes in estimated future development costs		(261,591		)		(391,318		)		(167,399		)
Sales and transfers of oil and gas produced during the period		(190,151		)		(179,384		)		(71,724		)
Net changes due to extensions, discoveries, and improved recovery		12,829				60,468				110,316
Net changes due to revisions of previous quantity estimates (1)		341,003				290,500				235,163
Previously estimated development costs incurred during the period		283,736				245,168				24,740
Accretion of discount		90,153				85,377				27,029
Purchase of minerals in place		218				217,791				234,336
Sale of minerals in place		(236,885		)		(354		)		(3,726		)
Changes in timing and other (2)		(91,088		)		22,436				824
Net change in income taxes		55,988				8,926				(92,620		)
Standardized measure of discounted future net cash flows		$	844,510			$	847,653			$	474,396
______________
(1)	The Company's net changes due to revisions of previous quantity estimates primarily reflect upward revisions to recoverable quantities of oil and gas minerals assuming existing prices and technology. For the year ended December 31, 2013, the Company made upward revisions of 6,148 MBbl of oil and natural gas liquids and 100,456 MMcf of natural gas due to additional information gathered from continued production from the shale areas and increases in estimated ultimate recoveries (EURs). For the year ended December 31, 2012, the Company made upward revisions of 12,568 MBbls of oil and natural gas liquids and 25,644 MMcf of natural gas.
(2)	The Company's changes in timing and other primarily represent changes in the Company's estimates of when proved reserve quantities will be realized. The reserves as of December 31, 2012, reflect accelerated recovery of minerals due to purchases of minerals in place and capital expenditures incurred to develop properties.
The commodity prices inclusive of adjustments for quality and location used in determining future net revenues related to the standardized measure calculation are as follows:
		2013				2012				2011
Oil (per Bbl)		$	93.13			$	88.37			$	96.19
Natural gas liquids (per Bbl)		$	43.79			$	53.94			$	44.25
Gas (per Mcf)		$	4.14			$	3.08			$	4.11

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	NOTE 16 - RELATED PARTY TRANSACTIONS
	The following table sets forth the related party balances as of December 31, 2013 and 2012:
		As of December 31,
		2013				2012
		(in thousands)
	Green Hunter (1)
	Accounts receivable - net	$	23			$	—
	Derivative assets (2)	$	79			$	264
	Investments (2)	$	2,262			$	3,009
	Notes receivable (2)	$	1,768			$	2,173
	Prepaid expenses	$	9			$	—
	The following table sets forth the related party transaction activities for the years ended December 31, 2013, 2012 and 2011:
				Years Ended
				December 31,
				2013				2012		2011
				(in thousands)
	GreenHunter
		Salt water disposal expense (1)		$	3,033			$	2,400	$	—
		Equipment rental expense (1)		$	282			$	1,000	$	1,300
		Office space rental expense (1)		$	13			—		—
		Professional services income (1)		$	—			$	—	$	162
		Interest income from note receivable (2)		$	205			$	191	$	—
		Dividends received from Series C shares		$	220			$	—	$	—
		Loss on investments (2)		$	730			1,333		$	—
	Pilatus Hunter, LLC
		Airplane rental expense (3)		$	166			$	174	$	463
	Executive of the Company
		Corporate apartment rental expense (4)		$	—			$	23	$	36
	_________________________________
	(1)	GreenHunter is an entity of which Gary C. Evans, Magnum Hunter's Chairman and CEO, is the Chairman, a major shareholder and former interim CEO; of which David Krueger, the Company's former Chief Accounting Officer and Senior Vice President, is the former Chief Financial Officer; and of which Ronald D. Ormand, the Company’s former Chief Financial Officer and Executive Vice President, is a former director. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources, Inc. ("Virco"), 100% owned subsidiaries of the Company, receive services related to salt water disposal and rental equipment from GreenHunter and its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services.
	(2)	On February 17, 2012, the Company sold its 100% owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a 100% owned subsidiary of GreenHunter.  The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. The Company has recorded interest income at the rate of 10% on the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and other long term assets and an available for sale investment in GreenHunter included in investments.
	(3)	The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense.
	(4)	During the years ended December 31, 2011 and 2012, the Company paid rent under a lease for a Houston, Texas corporate apartment from an executive of the Company, which apartment was used by other Company employees when in Houston for Company business.  The lease terminated in May 2012.
	In connection with the sale of Hunter Disposal, Triad Hunter entered into agreements with Hunter Disposal and GreenHunter Water for wastewater hauling and disposal capacity in Kentucky, Ohio, and West Virginia and a five-year tank rental agreement with GreenHunter Water.  See "Note 2 - Divestitures and Discontinued Operations".
	Mr. Evans, the Company's Chairman and Chief Executive Officer, was a 4.0% limited partner in TransTex Gas Services, LP ("TransTex Gas"). This limited partnership received total consideration of 622,641 Class A Common Units of Eureka Hunter Holdings and cash of $46.0 million upon the Company's acquisition of certain of its assets. This includes units issued in accordance with the agreement of Eureka Hunter Holdings and TransTex Gas to provide the limited partners of TransTex Gas the opportunity to purchase additional Class A Common Units of Eureka Hunter Holdings in lieu of a portion of the cash distribution they would otherwise receive. Certain limited partners purchased such units, including Mr. Evans, who purchased 27,641 Class A Common Units of Eureka Hunter Holdings for $553,000 which was the same purchase price equivalent offered to all TransTex investors.
	On February 17, 2012, the Company sold its wholly-owned subsidiary, Hunter Disposal, LLC, to GreenHunter Water, LLC, a wholly-owned subsidiary of GreenHunter Resources, Inc. The terms and conditions of the equity purchase agreement between the parties were approved by an independent special committee of the Board of the Company. Total consideration for the sale was approximately $9.3 million comprised of $2.2 million in cash, 1,846,722 shares of GreenHunter Resources, Inc. restricted common stock valued at $2.6 million based on a closing price of $1.79 per share, discounted for restrictions, 88,000 shares of GreenHunter Resources, Inc. 10% Series C Cumulative Preferred Stock with a fair value of $1.9 million, and a $2.2 million convertible promissory note which is convertible at the option of the Company into 880,000 shares of GreenHunter Resources, Inc. common stock based on the conversion price of $2.50 per share. The Company recognized a gain of on the sale of $2.4 million, in gain on disposal of discontinued operations, net of tax. The Company has recognized an embedded derivative asset resulting from the conversion option on the convertible promissory note with fair market value of $79,000 at December 31, 2013 and $264,000 at December 31, 2012. See "Note 3 - Fair Value of Financial Instruments". The cash proceeds from the sale were adjusted downward to $783,000 for changes in working capital and certain fees to reflect the effective date of the sale of December 31, 2012. The Company has recorded interest income as a result of the note receivable from GreenHunter Resources, Inc., in the amount of $204,760 for the year ended December 31, 2013. As a result of this transaction, the Company has an investment in GreenHunter Resources, Inc. that is included in derivatives and other long term assets and recorded under the equity method. The loss related to this investment was $0.7 million for the year ended December 31, 2013. In connection with the sale, Triad Hunter entered into agreements with Hunter Disposal, LLC and GreenHunter Water, LLC for wastewater hauling and disposal capacity in Kentucky, Ohio, and West Virginia and a five-year tank rental agreement with GreenHunter Water, LLC.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	NOTE 17 - COMMITMENTS AND CONTINGENCIES
	Legal Proceedings
	On April 23, 2013, Anthony Rosian, individually and on behalf of all other persons similarly situated, filed a class action complaint in the United States District Court, Southern District of New York, against the Company and certain of its officers, two of whom also serve as directors. On April 24, 2013, Horace Carvalho, individually and on behalf of all other persons similarly situated, filed a similar class action complaint in the United States District Court, Southern District of Texas, against the Company and certain of its officers, two of whom also serve as directors. Several substantially similar putative class actions have been filed in the Southern District of New York and in the Southern District of Texas. All such cases are collectively referred to as the Securities Cases. The cases filed in the Southern District of Texas have since been dismissed, but the cases in the Southern District of New York have been consolidated and remain ongoing.  The plaintiffs in the Securities Cases have filed a consolidated amended complaint alleging that the Company made certain false or misleading statements in its filings with the SEC, including statements related to the Company's internal and financial controls, the calculation of non-cash share-based compensation expense, the late filing of the Company's 2012 Form 10-K, the dismissal of Magnum Hunter's previous independent registered accounting firm, the Company’s characterization of the auditors’ position with respect to the dismissal, and other matters identified in the Company's April 16, 2013 Form 8-K, as amended.  The consolidated amended complaint asserts claims under Sections 10(b) and 20 of the Securities Exchange Act based on alleged false statements made regarding these issues throughout the alleged class period, as well as claims under Sections 11, 12, and 15 of the Securities Act based on alleged false statements and omissions regarding the Company’s internal controls made in connection with the 35,000,000-share secondary offering that Magnum Hunter completed on May 14, 2012.   The consolidated amended complaint demands that the defendants pay unspecified damages to the class action plaintiffs, including damages allegedly caused by the decline in the Company's stock price between February 22, 2013 and April 22, 2013. The Company and the individual defendants intend to vigorously defend the Securities Cases. It is possible that additional investor lawsuits could be filed over these events.
	On May 10, 2013, Steven Handshu filed a shareholder derivative suit in the 151st Judicial District Court of Harris County, Texas on behalf of the Company against the Company's directors and senior officers (the “Handshu Action”). On June 6, 2013, Zachariah Hanft filed another shareholder derivative suit in the Southern District of New York on behalf of the Company against the Company's directors and senior officers (the “Hanft Action”). On June 18, 2013, Mark Respler filed another shareholder derivative suit in the District of Delaware on behalf of the Company against the Company's directors and senior officers (the “Respler Action”).  On June 27, 2013, Timothy Bassett filed another shareholder derivative suit in the Southern District of Texas on behalf of the Company against the Company's directors and senior officers.  On September 16, 2013, Joseph Vitellone was substituted as plaintiff in the action filed by Mr. Bassett (the “Vitellone Action”).  These suits are collectively referred to as the Derivative Cases. The Derivative Cases assert that the individual defendants unjustly enriched themselves and breached their fiduciary duties to the Company by publishing allegedly false and misleading statements to the Company's investors regarding the Company's business and financial position and results, and allegedly failing to maintain adequate internal controls. The complaints demand that the defendants pay unspecified damages to the Company, including damages allegedly sustained by the Company as a result of the alleged breaches of fiduciary duties by the defendants, as well as disgorgement of profits and benefits obtained by the defendants, and reasonable attorneys', accountants' and experts' fees and costs to the plaintiff.  On December 13, 2013, the Handshu Action was dismissed for want of prosecution.  On December 20, 2013, the United States District Court for the Southern District of Texas granted the Company’s motion to dismiss the Vitellone Action and entered a final judgment dismissing the case in its entirety.  The court held that the plaintiff failed to allege particularized facts that would excuse them from making pre-suit demand on the Company’s Board of Directors as required by Delaware law.  On January 21, 2014, the Hanft Action was dismissed with prejudice after the plaintiff in that action filed a voluntary motion for dismissal.  On February 18, 2014, the District of Delaware granted the Company’s motion to dismiss the Respler Action on collateral estoppel grounds and closed the case. Accordingly, no shareholder derivative cases are currently pending against the Company’s officers and directors. It is possible, however, that additional shareholder derivative suits could be filed over these events
	In addition, the Company has received several demand letters from shareholders seeking books and records relating to the allegations in the Securities Cases and the Derivative Cases under Section 220 of the Delaware General Corporation Law.  On September 17, 2013, Anthony Scavo, who is one of the shareholders that made a demand, filed a books and records action in the Delaware Court of Chancery pursuant to Section 220 of the Delaware General Corporation Law (the “Scavo Action”).  The Scavo Action seeks various books and records relating to the claims in the Securities Cases and the Derivative Cases, as well as costs and attorneys’ fees.  The Company has filed an answer in the Scavo Action.  It is possible that additional similar actions may be filed and that similar shareholder demands could be made.
	The Company also received an April 26, 2013 letter from the SEC stating that the SEC's Division of Enforcement was conducting an inquiry regarding the Company's internal controls, change in outside auditors and public statements to investors and asking the Company to preserve documents relating to these matters. The Company is complying with this request.  On December 30, 2013, the Company received a document subpoena relating to the issues identified in the April 26, 2013 letter.  The Company is producing documents in response to the subpoena.
	Any potential liability from these claims cannot currently be estimated.
	Twin Hickory Matter
	On April 11, 2013, a flash fire occurred at Eureka Hunter Pipeline’s Twin Hickory site located in Tyler County, West Virginia.  The incident occurred during a pigging operation at a natural gas receiving station.  Two employees of third-party contractors received fatal injuries.  Another employee of a third-party contractor was injured.  In mid-February 2014, the estate of one of the deceased third-party contractor employees sued Eureka Hunter Pipeline and certain other parties in Karen S. Phipps v. Eureka Hunter Pipeline, LLC et al., Civil Action No. 14-C-41, in the Circuit Court of Ohio County, West Virginia. The plaintiff alleges that Eureka Hunter Pipeline and the other defendants engaged in certain negligent and reckless conduct which resulted in the wrongful death of the third-party contractor employee. The plaintiff has demanded judgment for an unspecified amount of compensatory, general and punitive damages. A pre-suit settlement demand has also been received from another potential claimant.  Investigation regarding the incident is ongoing.  It is not possible to predict at this juncture the extent to which, if at all,  Eureka Hunter Pipeline or any related entities will incur liability or damages because of this incident. However, we believe our insurance coverage will be sufficient to cover any losses or liabilities we may incur as a result of this incident.
	Agreement to Purchase Utica Shale Acreage
	On August 12, 2013, Triad Hunter entered into an asset purchase agreement, with MNW. MNW is an Ohio limited liability company that represents an informal association of various land owners, lessees and sub-lessees of mineral acreage who own or have rights in mineral acreage located in Monroe, Noble and/or Washington Counties, Ohio. Pursuant to the purchase agreement, Triad Hunter has agreed to acquire from MNW up to 32,000 net mineral acres, including currently leased and subleased acreage, located in such counties, over the next 10 months or possibly longer, subject to certain conditions. On October 7, 2013, Triad Hunter purchased 1,156.14 net leasehold acres for $4.9 million from MNW. On October 31, 2013, Triad Hunter purchased an additional 2,050.40 net leasehold acres for $8.7 million from MNW. On December 17, 2013, Triad Hunter purchased an additional 2,837.64 net leasehold acres for $10.9 million from MNW.
	Payable on Sale of Partnership
	On September 26, 2008, the Company sold its 5.33% limited partner interest in Hall-Houston Exploration II, L.P. pursuant to a Partnership Interest Purchase Agreement dated September 26, 2008, as amended on September 29, 2008. The interest was purchased by a non-affiliated partnership for a cash consideration of $8.0 million and the purchaser’s assumption of the first $1.4 million of capital calls subsequent to September 26, 2008.  The Company agreed to reimburse the purchaser for up to $754,255 of capital calls in excess of the first $1.4 million. The Company’s net gain on the sale of the asset is subject to future upward adjustment to the extent that some or all of the $754,255 is not called.  The liability as of December 31, 2013 and 2012 was $640,695.
	Operational Contingencies
	The exploration, development and production of oil and gas assets, the operations of oil and natural gas gathering systems, and the performance of oil field services are subject to various federal, state, local and foreign laws and regulations designed to protect the environment. Compliance with these regulations is part of the Company's day-to-day operating procedures. Infrequently, accidental discharge of such materials as oil, natural gas or drilling fluids can occur and such accidents can require material expenditures to correct. The Company maintains various levels and types of insurance which it believes to be appropriate to limit its financial exposure. The Company is unaware of any material capital expenditures required for environmental control during the year ending December 31, 2014.
	Operating Leases
	As of December 31, 2013, office space rentals with terms of 12 months or greater include office spaces in Houston, Texas, at a monthly cost of $33,000, office spaces in Grapevine, Texas, with monthly payments of approximately $4,800, and Williston Hunter subsidiaries office spaces in Denver, Colorado that have monthly payments of $5,800.
	Future minimum lease commitments under noncancellable operating leases at December 31, 2013, are as follows (in thousands):
	2014	$	504
	2015	$	457
	2016	$	239
	2017	$	121
	2018	$	127
	Thereafter	$	53
	Drilling Rig Purchase
	On May 7, 2013, the Company, through its wholly-owned subsidiary, Alpha Hunter Drilling, LLC, completed the purchase of a new drilling rig intended for use in the Utica and Marcellus Shale formations located in southeastern Ohio and western West Virginia. Costs to acquire and install the rig and components were $15.3 million as of December 31, 2013 .
	Gas Gathering and Processing Agreements
	On December 14, 2011, the Company entered into a 120 -month gas transportation contract. The contract became effective on August 1, 2012. The Company's remaining liability under the contract was approximately $21.9 million as of December 31, 2013. On June 27, 2012, Eureka Hunter Pipeline entered into 36-month gas compression contract. The contract became effective on October 1, 2012. The Company's remaining liability under the contract was $3.2 million as of December 31, 2013. With the Virco Acquisition, Triad Hunter assumed a 120-month gas transportation contract. The Company's remaining liability under the contract was $3.5 million as of December 31, 2013.
	Future minimum gathering, processing, and transportation commitments at December 31, 2013, are as follows (in thousands):
	2014	$	4,332
	2015	$	4,319
	2016	$	3,373
	2017	$	2,958
	2018	$	2,947
	Thereafter	$	10,722
	Eureka Hunter Holdings Operating Agreement
	Pursuant to the Eureka Hunter Holdings operating agreement, the number and composition of the board of directors of Eureka Hunter Holdings may change over time based on Ridgeline’s percentage ownership interest in Eureka Hunter Holdings (after taking into account any additional purchases of preferred units) or the failure of Eureka Hunter Holdings to satisfy certain performance goals by the third anniversary of the closing of the initial Ridgeline investment (or as of any anniversary after such date) or under certain other circumstances. The board of directors of Eureka Hunter Holdings is currently composed of a majority of members appointed by Magnum Hunter. Subject to the rights described above, the board of directors of Eureka Hunter Holdings may in the future be composed of an equal number of directors appointed by Magnum Hunter and Ridgeline or, in certain cases, of a majority of directors appointed by Ridgeline.
	If a change of control of Magnum Hunter occurs at any time prior to a qualified public offering (as defined in the Eureka Hunter Holdings operating agreement) of Eureka Hunter Holdings, Ridgeline will have the right under the terms of the operating agreement to purchase sufficient additional preferred units in Eureka Hunter Holdings so that it holds up to 51.0% of the equity ownership of Eureka Hunter Holdings.

CONDENSED_CONSOLIDATING_GUARAN

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	12 Months Ended
	Dec. 31, 2013
Guarantees [Abstract]	'
CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	'
	NOTE 18 - CONDENSED CONSOLIDATED GUARANTOR FINANCIAL STATEMENTS
	Debt Securities Under Universal Shelf Registration Statement
	Certain of the Company’s 100% owned subsidiaries, Shale Hunter, LLC, Triad Hunter, LLC, NGAS Hunter, LLC, Magnum Hunter Production, Inc., Williston Hunter, Inc., Williston Hunter ND, LLC, and Bakken Hunter, LLC (collectively, “Guarantor Subsidiaries”), have fully and unconditionally guaranteed the obligations of the Company under any debt securities that it may issue under a universal shelf registration statement on Form S-3, on a joint and several basis.
	These condensed consolidating guarantor financial statements have been retrospectively revised to reflect Eagle Ford Hunter as a non-guarantor as the subsidiary was no longer a guarantor upon the closing of the sale on April 24, 2013. See "Note 2 - Divestitures and Discontinued Operations".
	Condensed consolidating financial information for Magnum Hunter Resources Corporation, the Guarantor Subsidiaries and the other subsidiaries of the Company (the “Non Guarantor Subsidiaries”) as of December 31, 2013 and 2012 and for the years ended December 31, 2013, 2012, and 2011, was as follows:
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
			As of December 31, 2013
			Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries								Resources
			Corporation																Corporation
																			Consolidated
	ASSETS
	Current assets		$	53,161			$	28,825			$	42,112			$	(3,372	)		$	120,726
	Intercompany accounts receivable		965,138				—				—				(965,138		)		—
	Property and equipment (using successful efforts accounting)		7,214				1,124,637				382,228				—				1,514,079
	Investment in subsidiaries		372,236				102,314				—				(474,550		)		—
	Other assets		17,308				100,327				104,211				—				221,846
	Total Assets		$	1,415,057			$	1,356,103			$	528,551			$	(1,443,060	)		$	1,856,651
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities		$	54,826			$	86,115			$	46,334			$	(3,410	)		$	183,865
	Intercompany accounts payable		—				896,242				68,861				(965,103		)		—
	Long-term liabilities		818,651				23,115				143,615				—				985,381
	Redeemable preferred stock		100,000				—				136,675				—				236,675
	Shareholders' equity		441,580				350,631				133,066				(474,547		)		450,730
	Total Liabilities and Shareholders' Equity		$	1,415,057			$	1,356,103			$	528,551			$	(1,443,060	)		$	1,856,651
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
			As of December 31, 2012
			Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries								Resources
			Corporation																Corporation
																			Consolidated
	ASSETS
	Current assets		$	63,167			$	48,320			$	124,041			$	(31,209	)		$	204,319
	Intercompany accounts receivable		803,834				—				—				(803,834		)		—
	Property and equipment (using successful efforts accounting)		9,596				1,148,714				766,103				—				1,924,413
	Investment in subsidiaries		763,856				101,342				102,354				(967,552		)		—
	Other assets		20,849				5,341				43,710				—				69,900
	Total Assets		$	1,661,302			$	1,303,717			$	1,036,208			$	(1,802,595	)		$	2,198,632
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities		$	28,503			$	109,536			$	135,994			$	(30,377	)		$	243,656
	Intercompany accounts payable		—				611,932				191,902				(803,834		)		—
	Long-term liabilities		831,286				83,192				127,968				—				1,042,446
	Redeemable preferred stock		100,000				—				100,878				—				200,878
	Shareholders' equity		701,513				499,057				479,466				(968,384		)		711,652
	Total Liabilities and Shareholders' Equity		$	1,661,302			$	1,303,717			$	1,036,208			$	(1,802,595	)		$	2,198,632
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
			For the Year Ended December 31, 2013
			Magnum Hunter				Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries (1)								Resources
			Corporation																Corporation
																			Consolidated
	Revenues		$	2,629			$	187,095			$	95,286			$	(4,599	)		$	280,411
	Expenses		112,754				326,355				125,786				(10,135		)		554,760
	Loss from continuing operations before equity in net income of subsidiaries		(110,125		)		(139,260		)		(30,500		)		5,536				(274,349		)
	Equity in net income of subsidiaries		(298,775		)		(424		)		—				299,199				—
	Loss from continuing operations before income tax		(408,900		)		(139,684		)		(30,500		)		304,735				(274,349		)
	Income tax benefit		28,989				41,315				(7		)		—				70,297
Loss from continuing operations		(379,911		)		(98,369		)		(30,507		)		304,735				(204,052		)
Income from discontinued operations, net of tax		(7,813		)		13,101				(78,025		)		1,606				(71,131		)
Gain on disposal of discontinued operations, net of tax		144,378				(18,507		)		(66,707		)		(7,145		)		52,019
Net income (loss)		(243,346		)		(103,775		)		(175,239		)		299,196				(223,164		)
Net loss attributable to non-controlling interest		—				—				—				988				988
Net loss attributable to Magnum Hunter Resources Corporation		(243,346		)		(103,775		)		(175,239		)		300,184				(222,176		)
Dividends on preferred stock		(35,464		)		—				(21,241		)		—				(56,705		)
Net income (loss) attributable to common shareholders		$	(278,810	)		$	(103,775	)		$	(196,480	)		$	300,184			$	(278,881	)
		For the Year Ended December 31, 2012
		Magnum Hunter				Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
		Resources				Subsidiaries				Subsidiaries (1)								Resources
		Corporation																Corporation
																		Consolidated
Revenues		$	729			$	103,605			$	32,054			$	3,968			$	140,356
Expenses		54,047				159,603				49,597				16,077				279,324
Loss from continuing operations before equity in net income of subsidiaries		(53,318		)		(55,998		)		(17,543		)		(12,109		)		(138,968		)
Equity in net income of subsidiaries		(97,191		)		458				(23,362		)		120,095				—
Loss from continuing operations before income tax		(150,509		)		(55,540		)		(40,905		)		107,986				(138,968		)
Income tax benefit		5,937				13,375				—				—				19,312
Loss from continuing operations		(144,572		)		(42,165		)		(40,905		)		107,986				(119,656		)
Income from discontinued operations, net of tax		—				(11,036		)		(18,695		)		10,257				(19,474		)
Gain on disposal of discontinued operations, net of tax		—				2,409				—				—				2,409
Net income (loss)		(144,572		)		(50,792		)		(59,600		)		118,243				(136,721		)
Net income attributable to non-controlling interest		—				—				—				4,013				4,013
Net loss attributable to Magnum Hunter Resources Corporation		(144,572		)		(50,792		)		(59,600		)		122,256				(132,708		)
Dividends on preferred stock		(22,842		)		—				(11,864		)		—				(34,706		)
Net income (loss) attributable to common shareholders		$	(167,414	)		$	(50,792	)		$	(71,464	)		$	122,256			$	(167,414	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Operations
(in thousands)
		For the Year Ended December 31, 2011
		Magnum Hunter				Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
		Resources				Subsidiaries				Subsidiaries (1)								Resources
		Corporation																Corporation
																		Consolidated
Revenues		$	1,071			$	45,119			$	15,329			$	4,936			$	66,455
Expenses		68,772				39,226				16,949				1,184				126,131
Loss from continuing operations before equity in net income of subsidiaries		(67,701		)		5,893				(1,620		)		3,752				(59,676		)
Equity in net income of subsidiaries		(5,208		)		(2,196		)		(939		)		8,343				—
Loss from continuing operations before income tax		(72,909		)		3,697				(2,559		)		12,095				(59,676		)
Income tax benefit		—				3,727				(351		)		(514		)		2,862
Loss from continuing operations		(72,909		)		7,424				(2,910		)		11,581				(56,814		)
Income from discontinued operations, net of tax		—				(30,374		)		14,014				(3,238		)		(19,598		)
Gain on disposal of discontinued operations, net of tax		—				—				—				—				—
Net income (loss)		(72,909		)		(22,950		)		11,104				8,343				(76,412		)
Net income attributable to non-controlling interest		—				—				—				(249		)		(249		)
Net loss attributable to Magnum Hunter Resources Corporation		(72,909		)		(22,950		)		11,104				8,094				(76,661		)
Dividends on preferred stock		(14,007		)		—				—				—				(14,007		)
Net income (loss) attributable to common shareholders		$	(86,916	)		$	(22,950	)		$	11,104			$	8,094			$	(90,668	)
_______________________
(1) PRC Williston, LLC has been presented as a discontinued operation on a stand alone basis. Elimination entries have been recorded to eliminate discontinued operations treatment on a consolidated basis.
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Comprehensive Income (Loss)
(in thousands)
	For the Year Ended December 31, 2013
	Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter Resources
	Resources				Subsidiaries				Subsidiaries								Corporation
	Corporation																Consolidated
Net income (loss)	$	(243,346	)		$	(103,775	)		$	(175,239	)		$	299,196			$	(223,164	)
Foreign currency translation loss	—				—				(10,928		)		—				(10,928		)
Unrealized gain (loss) on available for sale securities	8,262				(84		)		—				—				8,178
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	(8,262		)		—				—				—				(8,262		)
Comprehensive income (loss)	(243,346		)		(103,859		)		(186,167		)		299,196				(234,176		)
Comprehensive income loss attributable to non-controlling interest	—				—				—				988				988
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(243,346	)		$	(103,859	)		$	(186,167	)		$	300,184			$	(233,188	)
	For the Year Ended December 31, 2012
	Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter Resources
	Resources				Subsidiaries				Subsidiaries								Corporation
	Corporation																Consolidated
Net income (loss)	$	(144,572	)		$	(50,792	)		$	(59,600	)		$	118,243			$	(136,721	)
Foreign currency translation loss	—				—				3,883				—				3,883
Unrealized gain (loss) on available for sale securities	—				(309		)		—				—				(309		)
Comprehensive income (loss)	(144,572		)		(51,101		)		(55,717		)		118,243				(133,147		)
Comprehensive (income) loss attributable to non-controlling interest	—				—				—				4,013				4,013
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(144,572	)		$	(51,101	)		$	(55,717	)		$	122,256			$	(129,134	)
	For the Year Ended December 31, 2011
	Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter Resources
	Resources				Subsidiaries				Subsidiaries								Corporation
	Corporation																Consolidated
Net income (loss)	$	(72,909	)		$	(22,950	)		$	11,104			$	8,343			$	(76,412	)
Foreign currency translation loss	—				—				(12,477		)		—				(12,477		)
Unrealized gain (loss) on available for sale securities	—				14				—				—				14
Comprehensive income (loss)	(72,909		)		(22,936		)		(1,373		)		8,343				(88,875		)
Comprehensive (income) loss attributable to non-controlling interest	—				—				—				(249		)		(249		)
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(72,909	)		$	(22,936	)		$	(1,373	)		$	8,094			$	(89,124	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Cash Flows
(in thousands)
		For the Year Ended December 31, 2013
		Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources				Subsidiaries				Subsidiaries								Resources
		Corporation																Corporation
																		Consolidated
Cash flow from operating activities		$	(371,351	)		$	376,129			$	106,933			$	—			$	111,711
Cash flow from investing activities		422,303				(387,660		)		(162,503		)		—				(127,860		)
Cash flow from financing activities		(29,929		)		(946		)		31,531				—				656
Effect of exchange rate changes on cash		—				—				(417		)		—				(417		)
Net increase (decrease) in cash		21,023				(12,477		)		(24,456		)		—				(15,910		)
Cash at beginning of period		26,872				(4,462		)		35,213				—				57,623
Cash at end of period		$	47,895			$	(16,939	)		$	10,757			$	—			$	41,713
		For the Year Ended December 31, 2012
		Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources				Subsidiaries				Subsidiaries								Resources
		Corporation																Corporation
																		Consolidated
Cash flow from operating activities		$	(458,921	)		$	275,914			$	241,018			$	—			$	58,011
Cash flow from investing activities		(364,045		)		(277,965		)		(367,197		)		—				(1,009,207		)
Cash flow from financing activities		831,080				(1,966		)		167,328				—				996,442
Effect of exchange rate changes on cash		—				—				(2,474		)		—				(2,474		)
Net increase (decrease) in cash		8,114				(4,017		)		38,675				—				42,772
Cash at beginning of period		18,758				(445		)		(3,462		)		—				14,851
Cash at end of period		$	26,872			$	(4,462	)		$	35,213			$	—			$	57,623
		For the Year Ended December 31, 2011
		Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources				Subsidiaries				Subsidiaries								Resources
		Corporation																Corporation
																		Consolidated
Cash flow from operating activities		$	(203,251	)		$	136,974			$	100,115			$	—			$	33,838
Cash flow from investing activities		(90,464		)		(136,489		)		(134,762		)		—				(361,715		)
Cash flow from financing activities		310,917				(310		)		31,586				—				342,193
Effect of exchange rate changes on cash		—				—				(19		)		—				(19		)
Net increase (decrease) in cash		17,202				175				(3,080		)		—				14,297
Cash at beginning of period		1,556				(620		)		(382		)		—				554
Cash at end of period		$	18,758			$	(445	)		$	(3,462	)		$	—			$	14,851
Senior Notes
Certain of the Company’s subsidiaries, including Alpha Hunter Drilling, LLC, Bakken Hunter, LLC, Shale Hunter, LLC, Hunter Aviation, LLC, Hunter Real Estate, LLC, Magnum Hunter Marketing, LLC, Magnum Hunter Production, Inc., Magnum Hunter Resources, GP, LLC, Magnum Hunter Resources, LP, NGAS Gathering, LLC, NGAS Hunter, LLC, PRC Williston, LLC, Triad Hunter, LLC, Williston Hunter, Inc., Williston Hunter ND, LLC, and Viking International Resources, Co., Inc. (collectively, "Guarantor Subsidiaries"), jointly and severally guarantee on a senior unsecured basis, the obligations of the Company under all the Senior Notes issued under the indenture entered into by the Company on May 16, 2012, as supplemented.
These condensed consolidating guarantor financial statements have been revised to reflect Eagle Ford Hunter as a non-guarantor as the subsidiary was no longer a guarantor upon the closing of the sale on April 24,2013. See "Note 2 - Divestitures and Discontinued Operations".
Condensed consolidating financial information for Magnum Hunter Resources Corporation , the Guarantor Subsidiaries and the other subsidiaries of the Company (the "Non Guarantor Subsidiaries") as of December 31, 2013 and 2012 and for the years ended December 31, 2013, 2012, and 2011 was as follows:
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Balance Sheets
(in thousands)
		As of December 31, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
ASSETS
Current assets		$	53,161			$	6,013			$	43,841			$	21,083			$	(3,372	)		$	120,726
Intercompany accounts receivable		965,138				—				—				—				(965,138		)		—
Property and equipment (using successful efforts accounting)		7,214				—				1,272,027				234,838				—				1,514,079
Investment in subsidiaries		372,236				—				102,314				—				(474,550		)		—
Other assets		17,308				—				100,894				103,644				—				221,846
Total Assets		$	1,415,057			$	6,013			$	1,519,076			$	359,565			$	(1,443,060	)		$	1,856,651
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities		$	54,826			$	2,035			$	97,520			$	32,894			$	(3,410	)		$	183,865
Intercompany accounts payable		—				45,661				921,237				(1,795		)		(965,103		)		—
Long-term liabilities		818,651				—				39,067				127,663				—				985,381
Redeemable preferred stock		100,000				—				—				136,675				—				236,675
Shareholders' equity (deficit)		441,580				(41,683		)		461,252				64,128				(474,547		)		450,730
Total Liabilities and Shareholders' Equity		$	1,415,057			$	6,013			$	1,519,076			$	359,565			$	(1,443,060	)		$	1,856,651
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Balance Sheets
(in thousands)
		As of December 31, 2012
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
ASSETS
Current assets		$	63,167			$	703			$	60,552			$	111,126			$	(31,229	)		$	204,319
Intercompany accounts receivable		803,834				—				—				—				(803,834		)		—
Property and equipment (using successful efforts accounting)		9,596				18,257				1,276,467				620,093				—				1,924,413
Investment in subsidiaries		763,856				—				101,341				102,354				(967,551		)		—
Other assets		20,849				—				5,451				43,600				—				69,900
Total Assets		$	1,661,302			$	18,960			$	1,443,811			$	877,173			$	(1,802,614	)		$	2,198,632
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities		$	28,503			$	2,291			$	117,511			$	125,727			$	(30,376	)		$	243,656
Intercompany accounts payable		—				58,966				508,254				236,636				(803,856		)		—
Long-term liabilities		831,286				1,274				97,271				112,615				—				1,042,446
Redeemable preferred stock		100,000				—				—				100,878				—				200,878
Shareholders' equity (deficit)		701,513				(43,571		)		720,775				301,317				(968,382		)		711,652
Total Liabilities and Shareholders' Equity		$	1,661,302			$	18,960			$	1,443,811			$	877,173			$	(1,802,614	)		$	2,198,632
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Operations
(in thousands)
		For the Year Ended December 31, 2013
		Magnum Hunter				PRC Williston, LLC (1)				100% Owned Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
Revenues		$	2,629			$	—			$	254,209			$	28,172			$	(4,599	)		$	280,411
Expenses		112,754				3,583				394,328				54,231				(10,136		)		554,760
Loss from continuing operations before equity in net income of subsidiaries		(110,125		)		(3,583		)		(140,119		)		(26,059		)		5,537				(274,349		)
Equity in net income of subsidiaries		(298,775		)		—				(424		)		—				299,199				—
Loss from continuing operations before income tax		(408,900		)		(3,583		)		(140,543		)		(26,059		)		304,736				(274,349		)
Income tax benefit		28,989				—				41,305				3				—				70,297
Loss from continuing operations		(379,911		)		(3,583		)		(99,238		)		(26,056		)		304,736				(204,052		)
Income from discontinued operations, net of tax		(7,813		)		(1,674		)		13,085				(76,335		)		1,606				(71,131		)
Gain on disposal of discontinued operations, net of tax		144,378				7,145				(18,507		)		(73,852		)		(7,145		)		52,019
Net income (loss)		(243,346		)		1,888				(104,660		)		(176,243		)		299,197				(223,164		)
Net loss attributable to non-controlling interest		—				—				—				—				988				988
Net loss attributable to Magnum Hunter Resources Corporation		(243,346		)		1,888				(104,660		)		(176,243		)		300,185				(222,176		)
Dividends on preferred stock		(35,464		)		—				—				(21,241		)		—				(56,705		)
Net income (loss) attributable to common shareholders		$	(278,810	)		$	1,888			$	(104,660	)		$	(197,484	)		$	300,185			$	(278,881	)
		For the Year Ended December 31, 2012
		Magnum Hunter				PRC Williston, LLC (1)				100% Owned Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
Revenues		$	729			$	—			$	122,703			$	12,955			$	3,969			$	140,356
Expenses		54,047				3,289				177,489				9,929				34,570				279,324
Loss from continuing operations before equity in net income of subsidiaries		(53,318		)		(3,289		)		(54,786		)		3,026				(30,601		)		(138,968		)
Equity in net income of subsidiaries		(97,191		)		—				458				(23,362		)		120,095				—
Loss from continuing operations before income tax		(150,509		)		(3,289		)		(54,328		)		(20,336		)		89,494				(138,968		)
Income tax benefit		5,937				—				13,375								—				19,312
Loss from continuing operations		(144,572		)		(3,289		)		(40,953		)		(20,336		)		89,494				(119,656		)
Income from discontinued operations, net of tax		—				(11,602		)		(11,056		)		(8,418		)		11,602				(19,474		)
Gain on disposal of discontinued operations, net of tax		—				—				2,409				—				—				2,409
Net income (loss)		(144,572		)		(14,891		)		(49,600		)		(28,754		)		101,096				(136,721		)
Net income attributable to non-controlling interest		—				—				—				—				4,013				4,013
Net loss attributable to Magnum Hunter Resources Corporation		(144,572		)		(14,891		)		(49,600		)		(28,754		)		105,109				(132,708		)
Dividends on preferred stock		(22,842		)		—				—				(11,864		)		—				(34,706		)
Net income (loss) attributable to common shareholders		$	(167,414	)		$	(14,891	)		$	(49,600	)		$	(40,618	)		$	105,109			$	(167,414	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Operations
(in thousands)
		For the Year Ended December 31, 2011
		Magnum Hunter				PRC Williston, LLC (1)				100% Owned Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
Revenues		$	1,071			$	—			$	54,545			$	5,903			$	4,936			$	66,455
Expenses		68,772				4,715				48,788				7,677				(3,821		)		126,131
Loss from continuing operations before equity in net income of subsidiaries		(67,701		)		(4,715		)		5,757				(1,774		)		8,757				(59,676		)
Equity in net income of subsidiaries		(6,906		)		—				(2,196		)		(939		)		10,041				—
Loss from continuing operations before income tax		(74,607		)		(4,715		)		3,561				(2,713		)		18,798				(59,676		)
Income tax benefit		—				—				3,733				(357		)		(514		)		2,862
Loss from continuing operations		(74,607		)		(4,715		)		7,294				(3,070		)		18,284				(56,814		)
Income from discontinued operations, net of tax		—				1,698				(30,364		)		12,306				(3,238		)		(19,598		)
Gain on disposal of discontinued operations, net of tax		—				—				—				—				—				—
Net income (loss)		(74,607		)		(3,017		)		(23,070		)		9,236				15,046				(76,412		)
Net income attributable to non-controlling interest		—				—				—				—				(249		)		(249		)
Net loss attributable to Magnum Hunter Resources Corporation		(74,607		)		(3,017		)		(23,070		)		9,236				14,797				(76,661		)
Dividends on preferred stock		(14,007		)		—				—				—				—				(14,007		)
Net income (loss) attributable to common shareholders		$	(88,614	)		$	(3,017	)		$	(23,070	)		$	9,236			$	14,797			$	(90,668	)
_________________
(1) PRC Williston, LLC has been presented as a discontinued operation on a stand alone basis. Elimination entries have been recorded to eliminate discontinued operations treatment on a consolidated basis.
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Comprehensive Income (Loss)
(in thousands)
	For the Year Ended December 31, 2013
	Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
	Resources								Subsidiaries				Subsidiaries								Resources
	Corporation																				Corporation
																					Consolidated
Net income (loss)	$	(243,346	)		$	1,888			$	(104,660	)		$	(176,243	)		$	299,197			$	(223,164	)
Foreign currency translation loss	—				—				—				(10,928		)		—				(10,928		)
Unrealized gain (loss) on available for sale securities	8,262				—				(84		)		—				—				8,178
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	(8,262		)		—				—				—				—				(8,262		)
Comprehensive income (loss)	(243,346		)		1,888				(104,744		)		(187,171		)		299,197				(234,176		)
Comprehensive (income) loss attributable to non-controlling interest	—				—				—				—				988				988
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(243,346	)		$	1,888			$	(104,744	)		$	(187,171	)		$	300,185			$	(233,188	)
	For the Year Ended December 31, 2012
	Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
	Resources								Subsidiaries				Subsidiaries								Resources
	Corporation																				Corporation
																					Consolidated
Net income (loss)	$	(144,572	)		$	(14,891	)		$	(49,600	)		$	(28,754	)		$	101,096			$	(136,721	)
Foreign currency translation loss	—				—				—				3,883				—				3,883
Unrealized gain (loss) on available for sale securities	—				—				(309		)		—				—				(309		)
Comprehensive income (loss)	(144,572		)		(14,891		)		(49,909		)		(24,871		)		101,096				(133,147		)
Comprehensive (income) loss attributable to non-controlling interest	—				—				—				—				4,013				4,013
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(144,572	)		$	(14,891	)		$	(49,909	)		$	(24,871	)		$	105,109			$	(129,134	)
	For the Year Ended December 31, 2011
	Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
	Resources								Subsidiaries				Subsidiaries								Resources
	Corporation																				Corporation
																					Consolidated
Net income (loss)	$	(74,607	)		$	(3,017	)		$	(23,070	)		$	9,236			$	15,046			$	(76,412	)
Foreign currency translation loss	—				—				—				(12,477		)		—				(12,477		)
Unrealized gain (loss) on available for sale securities	—				—				14				—				—				14
Comprehensive income (loss)	(74,607		)		(3,017		)		(23,056		)		(3,241		)		15,046				(88,875		)
Comprehensive (income) loss attributable to non-controlling interest	—				—				—				—				(249		)		(249		)
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(74,607	)		$	(3,017	)		$	(23,056	)		$	(3,241	)		$	14,797			$	(89,124	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Cash Flows
(in thousands)
		For the Year Ended December 31, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
Cash flow from operating activities		$	(371,351	)		$	(1,932	)		$	397,213			$	101,085			$	(13,304	)		$	111,711
Cash flow from investing activities		422,303				15,236				(411,473		)		(153,926		)		—				(127,860		)
Cash flow from financing activities		(29,929		)		(13,304		)		796				29,789				13,304				656
Effect of exchange rate changes on cash		—				—				—				(417		)		—				(417		)
Net increase (decrease) in cash		21,023				—				(13,464		)		(23,469		)		—				(15,910		)
Cash at beginning of period		26,872				—				(4,187		)		34,938				—				57,623
Cash at end of period		$	47,895			$	—			$	(17,651	)		$	11,469			$	—			$	41,713
		For the Year Ended December 31, 2012
		Magnum Hunter				PRC Williston, LLC				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
Cash flow from operating activities		$	(458,921	)		$	1,256			$	281,782			$	235,104			$	(1,210	)		$	58,011
Cash flow from investing activities		(364,045		)		(49		)		(287,204		)		(357,912		)		3				(1,009,207		)
Cash flow from financing activities		831,080				(1,207		)		1,781				163,581				1,207				996,442
Effect of exchange rate changes on cash		—				—				—				(2,474		)		—				(2,474		)
Net increase (decrease) in cash		8,114				—				(3,641		)		38,299				—				42,772
Cash at beginning of period		18,758				—				(546		)		(3,361		)		—				14,851
Cash at end of period		$	26,872			$	—			$	(4,187	)		$	34,938			$	—			$	57,623
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Cash Flows
(in thousands)
		For the Year Ended December 31, 2011
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
Cash flow from operating activities		$	(203,251	)		$	(1,738	)		$	138,855			$	98,048			$	1,924			$	33,838
Cash flow from investing activities		(90,464		)		(175		)		(141,954		)		(129,111		)		(11		)		(361,715		)
Cash flow from financing activities		310,917				1,913				3,206				28,070				(1,913		)		342,193
Effect of exchange rate changes on cash		—				—				—				(19		)		—				(19		)
Net increase (decrease) in cash		17,202				—				107				(3,012		)		—				14,297
Cash at beginning of period		1,556				—				(653		)		(349		)		—				554
Cash at end of period		$	18,758			$	—			$	(546	)		$	(3,361	)		$	—			$	14,851

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
SUBSEQUENT EVENTS	'
	NOTE 19 - SUBSEQUENT EVENTS
	Master Loan and Security Agreement
	On January 21, 2014, Alpha Hunter Drilling, LLC entered into a Master Loan and Security Agreement with CIT Finance to borrow $5.6 million at an interest rate of 7.94% over a term of forty-eight months. The note is collateralized by field equipment, and the Company is a guarantor on the note.
	Derivative Contracts
	We entered into commodity derivative contracts subsequent to December 31, 2013, through the date of this report. Our objective for holding these commodity derivatives is to protect the operating revenues and cash flows related to a portion of our future natural gas and crude oil sales from the risk of significant declines in commodity prices, which helps insure our ability to fund our capital expenditure budget.  We have not designated any of these commodity derivatives as hedges under ASC 815.
	The table below is a summary of our commodity derivatives entered into subsequent to December 31, 2013 through the date of this report:
				Weighted Avg
	Natural Gas	Period	MMBTU/day	Price per MMBTU
	Swaps	Jan 2014 - Dec 2014	21,000	$4.27
		Jan 2015 - Dec 2015	20,000	$4.18
	Ceilings purchased (call)	Jan 2014 - Dec 2014	6,000	$5.50
	Common Stock Granted to Employees, Management and Board Members
	On January 8, 2014, the Company granted 1,312,575 restricted shares of common stock to officers, executives, and employees of the Company. The shares vest over a 3-year period with 33% of the options vesting one year from the date of the grant. The Company also granted 123,798 restricted shares to the directors of the Company which vest 100% one year from the date of the grant.
	Issuance of Series A Preferred Units of Eureka Hunter Holdings
	Eureka Hunter Holdings has issued 97,492 Series A Preferred units with a redemption value of $1.9 million for dividends paid in kind subsequent to December 31, 2013.
	Settlement Agreement with Seminole Energy Services
	On January 10, 2014, the company and certain of its subsidiaries entered into an Omnibus Settlement Agreement and Release dated January 9, 2014 with Seminole Energy Services, LLC and certain of its affiliates (collectively, "Seminole"). In connection with and pursuant to the terms of the Settlement Agreement, the Company and Seminole have agreed to release and discharge each other from all claims and causes of action alleged in, arising from or related to certain legal proceedings and terminate, amend and enter into certain new, related agreements effective immediately prior to year-end on December 31, 2013 (the "New Agreements").
	By entering into the New Agreements, the Company and Seminole have restructured their existing agreements. The Company obtained a reduction in gas gathering rates it will pay for natural gas gathered on the Stone Mountain Gathering System that the Company owns or controls. The Company and Seminole collectively agreed to construct an enhancement of the Rogersville Plant designed to recover less ethane and more propane from the natural gas processed at the Rogersville Plant and reduce and extend the Company's contractual horizontal well drilling obligations owed to Seminole. The Company and Seminole have also agreed to modify the natural gas processing rates the Company will pay for processing at the Rogersville Plant, the Company's allocation of natural gas liquids ("NGL") recovered from gas processed and the costs of blend stock necessary to blend with the NGL produced from the Rogersville Plant, and certain deductions to the NGL purchase price the Company will pay Seminole for the Company's NGL produced from the Rogersville Plant. Seminole sold to the Company Seminole's 50% interest in a natural gas gathering trunk line and treatment facility located in southwestern Muhlenberg County, Kentucky, which had previously been owned equally by Seminole and the Company.
	As a result of the restructuring effected by the Settlement Agreement, the Company expects to realize operational savings, certain components of which savings would occur over time, depending on the implementation timing or completion of certain of the benefits provided to the Company.
	Sale of Certain other Eagle Ford Shale Assets
	On January 28, 2014, the Company and certain of its affiliates closed on the sale of certain of its oil and gas properties and related assets in the Eagle Ford Shale in South Texas to New Standard Energy Texas LLC (“NSE Texas”), a subsidiary of New Standard Energy Limited (“NSE”), an Australian Securities Exchange-listed Australian company.
	The divested properties and assets consisted primarily of leasehold acreage in Atascosa County, Texas and working interests in five horizontal wells, four of which wells were operated by the Company (the “Eagle Ford Assets”). The effective date of the sale was December 1, 2013. As consideration for the Eagle Ford Assets, the Company received aggregate purchase price consideration of $15 million in cash (before taking into account customary purchase price adjustments) and 65,650,000 ordinary shares of NSE valued, for purposes of the calculation of the purchase price, at approximately $9.5 million. This represents approximately 17% of the total shares outstanding of NSE.
	In connection with the closing of the sale, Shale Hunter, LLC, a subsidiary of the Company (“Shale Hunter”), and NSE Texas entered into a Transition Services Agreement (the “TSA”). The TSA provides that, during a specified transition period, Shale Hunter will provide NSE Texas with certain transitional services relating to the Eagle Ford Assets for a fee.
	Upon and as a result of the closing of the sale of the Eagle Ford Assets on January 28, 2014, the borrowing base under the Company’s asset-based, senior secured revolving credit facility maturing April 13, 2016 was automatically reduced by $10 million to $232.5 million as of the closing pursuant to the terms of the Company’s Third Amended and Restated Credit Agreement, dated as of December 13, 2013, by and among the Company, as borrower, certain of its subsidiaries, as guarantors, Bank of Montreal, as administrative agent, the lenders party thereto and the agents party thereto.

ORGANIZATION_NATURE_OF_OPERATI1

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Presentation of Consolidated Financial Statements	'
	Presentation of Consolidated Financial Statements
	The consolidated financial statements include the accounts of the Company and entities in which it holds a controlling interest. Our financial statements are prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). All significant intercompany balances and transactions have been eliminated. The preparation of our financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses. These estimates are based on information that is currently available to us and on various other assumptions that it believes to be reasonable under the circumstances. Actual results could differ from those estimates under different assumptions and conditions. Significant estimates are required for proved oil and gas reserves which may have a material impact on the carrying value of oil and gas property, and of assets held for sale.
Reclassification of Prior-Year Balances	'
	Reclassification of Prior-Year Balances
	Certain prior-year balances in the consolidated financial statements have been reclassified to correspond with current-year classifications.
Cash and cash equivalents	'
	Cash and cash equivalents
	Cash and cash equivalents include cash in banks and highly liquid debt securities that have original maturities of three months or less.
Financial instruments	'
	Financial Instruments
	The carrying amounts of financial instruments including cash and cash equivalents, accounts receivable, notes receivable, accounts payable and accrued liabilities, derivatives, and certain long-term debt approximate fair value as of December 31, 2013 and 2012.
Inventory	'
	Inventory
	The Company’s materials and supplies inventory is primarily comprised of frac sand used in the completion process of hydraulic fracturing. Frac sand is acquired for use in future well completion operations or repair operations and is carried at the lower of cost or market, on a first-in, first-out cost basis. “Market,” in the context of inventory valuation, represents net realizable value, which is the amount that the Company is allowed to bill to the joint accounts under joint operating agreements to which the Company is a party. Valuation reserve allowances for materials and supplies inventories are recorded as reductions to the carrying values of the materials and supply inventories in the Company’s consolidated balance sheets and as operating expense in the accompanying consolidated statements of operations. As of December 31, 2012 , the Company estimated that $3.5 million of its frac sand inventory would not be utilized within one year. Accordingly, those inventory values were classified as other long term assets in the accompanying consolidated balance sheet as of December 31, 2012. As of December 31, 2013 the frac sand inventory is anticipated to be entirely used within the coming year, and all inventories are classified as current.
	Commodities inventories are carried at the lower of average cost or market, on a first-in, first-out basis. The Company’s commodities inventories consist of crude oil held in storage and is carried at the lower of average cost or market, on a first in, first out basis. Any valuation allowances of commodities inventories are recorded as reductions to the carrying values of the commodities inventories included in the Company’s consolidated balance sheets and as charges to lease operating expense in the consolidated statements of operations.
Oil and Natural Gas Properties	'
	Oil and Natural Gas Properties
	Capitalized Costs
	Our oil and natural gas properties comprised the following:
		December 31,
		2013			2012
		(in thousands)
	Mineral interests in properties:
	Unproved leasehold costs	$	469,337		$	645,164
	Proved leasehold costs	336,357			454,556
	Wells and related equipment and facilities	438,275			727,711
	Uncompleted wells, equipment and facilities	97,748			71,665
	Advances to operators for wells in progress	13,571			9,563
	Total costs	1,355,288			1,908,659
	Less accumulated depreciation, depletion, and amortization	(130,629		)	(186,156		)
	Net capitalized costs	$	1,224,659		$	1,722,503
	The Company follows the successful efforts method of accounting for oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties and to drill and equip new development wells and related asset retirement costs are capitalized. Costs to acquire mineral interests and drill exploratory wells are also capitalized pending determination of whether the wells have proved reserves or not. If the Company determines that the wells do not have proved reserves, the costs are charged to exploration expense. Geological and geophysical costs, including seismic studies and related costs of carrying and retaining unproved properties are charged to exploration expense as incurred.
	On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depreciation, depletion, and amortization are eliminated from the property accounts, and the resultant gain or loss is recognized. On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated depreciation, depletion, and amortization with no resulting gain or loss recognized in income. A sale of an entire field is generally treated as discontinued operations.
	Leasehold costs attributable to proved oil and gas properties are depleted by the unit-of-production method over total proved reserves. Capitalized development costs are depleted by the unit-of-production method over producing proved reserves. Depreciation, depletion, amortization and accretion expense for oil and gas producing property and related equipment was $69.0 million, $49.2 million, and $18.4 million for the years ended December 31, 2013, 2012, and 2011, respectively.
	Unproved oil and gas leasehold costs that are individually significant are periodically assessed for impairment of value by comparing current quotes and recent acquisitions, and taking into account management's intent, and a loss is recognized at the time of impairment by providing an impairment allowance in exploration expense.
	Capitalized costs related to proved oil and gas properties, including wells and related equipment and facilities, are evaluated for impairment quarterly based on an analysis of undiscounted future net cash flows. If undiscounted future net cash flows are insufficient to recover the net capitalized costs related to proved properties, then the Company recognizes an impairment charge in income from operations equal to the difference between the net capitalized costs related to proved properties and their estimated fair values based on the present value of the related future net cash flows and other relevant market value data. Impairment of proved oil and gas properties is calculated on a field by field basis.
	It is common for operators of oil and gas properties to request that joint interest owners pay for large expenditures, typically for drilling new wells, in advance of the work commencing. This right to call for cash advances is typically a provision of the joint operating agreement that working interest owners in a property adopt. The Company records these advance payments to Advances in the property accounts and reclassifies amounts from this account when the actual expenditure is later billed to us by the operator.
	If an unproved property is sold or the lease expires without identifying proved reserves, the cost of the property is charged to the impairment allowance. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.
Estimates of Proved Oil and Natural Gas Reserves	'
	Estimates of Proved Oil and Natural Gas Reserves
	Estimates of our proved reserves included in this report are prepared in accordance with U.S. SEC guidelines for reporting corporate reserves and future net revenue. The accuracy of a reserve estimate is a function of:
	·      the quality and quantity of available data;
	·      the interpretation of that data;
	·      the accuracy of various mandated economic assumptions; and
	·      the judgment of the persons preparing the estimate.
	Our proved reserve information included in this report was predominately based on evaluations reviewed by independent third party petroleum engineers. Estimates prepared by other third parties may be higher or lower than those included herein. Because these estimates depend on many assumptions, all of which may substantially differ from future actual results, reserve estimates will be different from the quantities of oil and gas that are ultimately recovered. In addition, results of drilling, testing and production after the date of an estimate may justify material revisions to the estimate.
	In accordance with SEC requirements, the Company based the estimated discounted future net cash flows from proved reserves on the unweighted arithmetic average of the  prior 12-month commodity prices as of the first day of each of the months constituting the period and costs on the date of the estimate.
	The estimates of proved reserves materially impact depreciation, depletion, amortization and accretion (DDA&A) expense. If the estimates of proved reserves decline, the rate at which the Company records DDA&A expense will increase, reducing future net income. Such a decline may result from lower market prices, which may make it uneconomic to drill for and produce from higher-cost fields.
Revenue Recognition	'
	Revenue Recognition
	Revenues associated with sales of crude oil, natural gas, and natural gas liquids are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry.
	Revenues from the production of natural gas and crude oil from properties in which the Company has an interest with other producers are recognized based on the actual volumes sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be non-recoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropriate. Cumulative differences between volumes sold and entitlement volumes are generally not significant.
Accounts Receivable	'
	Accounts Receivable
	The Company recognizes revenue for our production when the quantities are delivered to or collected by the respective purchaser. Prices for such production are defined in sales contracts and are readily determinable or estimable based on available data.
	Accounts receivable from joint interest owners consist of joint interest owner obligations due within 30 days of the invoice date. Accounts receivable, oil and gas sales, consist of accrued revenues due under normal trade terms, generally requiring payment within 30 to 60 days of production. The Company reviews accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible.
Revenue Payable	'
	Revenue Payable
	Revenue payable represents amounts collected from purchasers for oil and gas sales which are either revenues due to other working or royalty interest owners or severance taxes due to the respective state or local tax authorities. Generally, the Company is required to remit amounts due under these liabilities within 30 days of the end of the month in which the related production occurred.
Lease Operating Expenses	'
	Lease Operating Expenses
	Lease operating expenses, including compressor rental and repair, pumpers’ salaries, saltwater disposal, ad valorem taxes, insurance, repairs and maintenance, workovers and other operating expenses are expensed as incurred. Transportation, gathering, and processing costs are expensed as incurred and included in lease operating expenses.
Exploration	'
	Exploration
	Exploration expense consists primarily of impairment reserves for abandonment costs associated with unproved properties for which the Company has no further exploration or development plans, exploratory dry hole costs, and geological and geophysical costs.
Severance Taxes and Marketing Costs	'
	Severance Taxes and Marketing Costs
	Severance taxes are comprised of production taxes charged by most states on oil, natural gas, and natural gas liquids produced. These taxes are computed on the basis of volumes and/or value of production or sales. These taxes are usually levied at the time and place the minerals are severed from the producing reservoir. Marketing costs are those directly associated with marketing our production and are based on volumes.
Gas Gathering and Processing Costs	'
	Gas Gathering and Processing Costs
	Gas gathering and processing costs are those costs associated with oil and gas gathering revenues of our midstream operations.
Dependence on Major Customers	'
	Dependence on Major Customers
	The Company's share of oil and gas production is sold to various purchasers who must be prequalified under the Company's credit risk policies and procedures. The Company records allowances for doubtful accounts based on the age of accounts receivables and the financial condition of its purchasers and, depending on facts and circumstances, may require purchasers to provide collateral or otherwise secure their accounts. The loss of any one significant purchaser could have a material, adverse effect on the ability of the Company to sell its oil and gas production in a certain region. Although the Company is exposed to a concentration of credit risk, it believes that all of its purchasers are credit worthy.
Dependence on Suppliers	'
	Dependence on Suppliers
	Our industry is cyclical, and from time to time there is a shortage of drilling rigs, fracture stimulation services, equipment, related supplies and qualified personnel. During these periods, the costs and delivery times of rigs, equipment and supplies are substantially greater. If the unavailability or high cost of drilling rigs, equipment, supplies or qualified personnel were particularly severe in the areas where the Company operates, it could be materially and adversely affected. The Company believes that there are potential alternative providers of drilling services and that it may be necessary to establish relationships with new contractors as our activity level increases and capital program grows. However, there can be no assurance that the Company can establish such relationships and that those relationships will result in increased availability of drilling rigs.
Gas Transportation, Gathering, Processing Equipment	'
	Gas Transportation, Gathering and Processing Equipment and Other
	Our gas gathering system assets and field servicing assets are carried at cost. The Company capitalizes interest on expenditures for significant construction projects that last more than six months while activities are in progress to bring the assets to their intended use. Interest of $2.6 million and $4.4 million was capitalized on our Eureka Hunter Gas Gathering System during the years ended 2013 and 2012, respectively. The Company did not capitalize any interest in 2011. Depreciation of gas gathering system assets is provided using the straight line method over an estimated useful life of fifteen years. Depreciation of field servicing assets is provided using the straight line method over various useful lives ranging from three to ten years. Gain or loss on retirement or sale or other disposition of assets is included in income in the period of disposition.
	Furniture, fixtures and equipment are carried at cost. Depreciation of furniture, fixtures and equipment is provided using the straight-line method over estimated useful lives ranging from five to fifteen years. Gain or loss on retirement or sale or other disposition of assets is included in other income in the period of disposition.
	Such equipment is comprised of the following:
		December 31,
		2013			2012
		(in thousands)
	Gas transportation, gathering and processing equipment and other	$	315,642		$	218,656
	Less accumulated depreciation and depletion	(26,222		)	(16,746		)
	Net capitalized costs	$	289,420		$	201,910
	Depreciation expense for other property and equipment was $15.6 million, $8.1 million, and $7.8 million, for the years ended December 31, 2013, 2012, and 2011, respectively.
	TransTex Hunter sells and leases gas treating and processing equipment, much of which is leased to third party operators for treating gas at the wellhead. The leases generally have a term of three years or less. The equipment under leases in place as of December 31, 2013 had terms for future payments extending as far as December 2016.
Deferred Financing Costs	'
	Deferred Financing Costs
	In connection with debt financings, the Company paid $1.2 million and $20.3 million in fees in the year ended December 31, 2013, and 2012, respectively. These fees were recorded as deferred financing costs and are being amortized over the life of the debt instrument using the straight line method for debt in the form of a line of credit and effective interest method for term loans.
Commodity and Financial Derivative Instruments	'
	Commodity and Financial Derivative Instruments
	The Company uses commodity and financial derivative instruments, typically options and swaps, to manage the risk associated with fluctuations in oil and gas prices, and the Company accounts for these instruments in accordance with ASC 815 - Derivatives and Hedging. The Company also has an embedded derivative liability resulting from certain conversion features, redemption options, and other features of our Series A Convertible Preferred Units of Eureka Hunter Holdings, LLC and an embedded derivative asset resulting from the bifurcated conversion feature associated with the convertible note received as partial consideration upon the sale of Hunter Disposal, LLC. See "Note 3 - Fair Value of Financial Instruments", "Note 2 - Divestitures and Discontinued Operations", "Note 10 - Shareholders' Equity", and "Note 16 - Related Party Transactions".
	Derivative instruments are recorded at fair value in the balance sheet as either an asset or liability, with those contracts maturing in the next twelve months classified as current, and those maturing thereafter as long-term. The Company recognizes changes in the derivatives' fair values in earnings, as it has not designated our oil and gas price derivative contracts as cash flow hedges. The Company recognizes the gains and losses on settled and open transactions on a net basis within the “Gain (loss) on derivative contracts” line item within the “Other Income (expense)” section of the Consolidated Statement of Operations.
Investments	'
	Investments
	Investments are comprised of common and preferred stock of companies publicly traded on the TSX Venture Exchange and the NYSE MKT (formerly NYSE Amex) with quoted prices in active markets. On February 17, 2012, the Company received 1,846,722 restricted common shares of GreenHunter Resources, Inc., which has a carrying value of $0.6 million and $1.3 million at December 31, 2013 and 2012, respectively, and 88,000 shares of GreenHunter Resources, Inc. 10% Series C Preferred Stock, which has a fair value of $1.7 million and $1.7 million at December 31, 2013 and 2012, respectively, as partial consideration for the sale by our wholly-owned subsidiary, Triad Hunter, LLC, of its equity ownership interest in Hunter Disposal, LLC to GreenHunter Resources, Inc. The GreenHunter common stock investment is accounted for under the equity method within the scope of ASC 323: Investments - Equity Method. The Company initially accounted for its investment in GreenHunter’s Series C Preferred Stock under the cost method specified in ASC 325: Investments - Other. The preferred shares were cost basis investments from February 17, 2012 through July 31, 2012, since the preferred stock was not publicly traded and did not have a readily determinable fair value, and therefore ineligible for accounting under ASC 320: Investments - Debt and Equity Securities.
	Beginning July 31, 2012, the GreenHunter Series C Preferred Stock is publicly traded with a readily determinable fair value and is classified as available for sale within the scope of ASC 320. Available-for-sale assets are securities and other financial investments that are neither held for trading, nor held to maturity, nor held for strategic reasons, and that have a readily available market price. As such, the gains and losses resulting from marking available-for-sale investments to market are not included in net income but are reflected in other comprehensive income until they are realized.
Goodwill and Intangible Assets	'
	Goodwill and Other Intangible Assets
	During 2012, the Company recorded goodwill associated with the acquisition of the assets of TransTex Gas Services, LP, which represents the fair value of the acquired entity over the net amounts assigned to assets acquired and liabilities assumed. In accordance with GAAP, goodwill is not amortized to earnings, but is assessed annually in April for impairment, or whenever events or circumstances indicate that impairment of the carrying value of goodwill is likely. The Company has established April 1 as the annual testing date. If the carrying value of goodwill is determined to be impaired, it is reduced to its implied fair value with a corresponding charge to pretax earnings in the period in which it is determined to be impaired. Financial Accounting Standards Board ("FASB") Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350) permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. The Company used this approach, and performed a full qualitative analysis of the need for impairment as of April 1, 2013. The Company performed a follow up analysis to determine if there were any triggering events as of December 31, 2013, and if an interim analysis was necessary, and none were determined to exist, as TransTex Gas Services, LP has experienced positive results on the Company's performance measures, and it has not experienced any significant adverse conditions.
	Intangible assets consist primarily of the fair value of the acquired gas treating agreements and customer relationships in the TransTex Gas Services, LP assets acquisition.  The intangible assets were valued at fair value using a discounted cash flow model with a discount rate at the date of acquisition of 13%.  Such assets are being amortized over the weighted average term of 8.5 years.  The customer relationships are being amortized with a 12.5 year life.
Assets Held for Sale	'
	Assets Held for Sale
	Assets held for sale as of December 31, 2013 relate to the Company's interests in (i) Magnum Hunter Production, Inc. (“MHP”), a wholly-owned subsidiary of the Company whose oil and natural gas operations are located primarily in the southern Appalachian Basin in Kentucky and Tennessee, and (ii) the Canadian operations of Williston Hunter Canada, Inc., a wholly-owned subsidiary of the Company ("WHI Canada"). The Company is actively marketing these interests and anticipates completing the divestitures by the second quarter of 2014.
Asset Retirement Obligation	'
	Asset Retirement Obligation
	The asset retirement obligation ("ARO") primarily represents the estimated present value of the amount the Company will incur to plug, abandon and remediate our producing properties at the projected end of their productive lives, in accordance with applicable federal, state and local laws. The Company determined its ARO by calculating the present value of estimated cash flows related to the obligation. The retirement obligation is recorded as a liability at its estimated present value as of the asset’s inception, with an offsetting increase to proved properties. Periodic accretion of discount of the estimated liability is recorded as accretion expense in the consolidated statements of operations.
	The liability is determined using significant assumptions, including current estimates of plugging and abandonment costs, annual inflation of these costs, the productive lives of wells and our risk-adjusted interest rate. Changes in any of these assumptions can result in significant revisions to the estimated ARO.
Share-based Compensation	'
	Share-Based Compensation
	The Company estimates the fair value of share-based payment awards made to employees and directors, including stock options, restricted stock and matching contributions of stock to employees under our employee stock ownership plan, on the date of grant using an option-pricing model. The value of the portion of the award that is ultimately expected to vest is recognized as an expense ratably over the requisite service periods. Awards that vest only upon achievement of performance criteria are recorded only when achievement of the performance criteria is considered probable. The Company estimated the fair value of each share-based award using the Black-Scholes option pricing model or a lattice model. These models are highly complex and dependent on key estimates by management. The estimates with the greatest degree of subjective judgment are the estimated lives of the stock-based awards, the estimated volatility of our stock price, and the assessment of whether the achievement of performance criteria is probable.
Income Taxes	'
	Income Taxes
	Income taxes are accounted for in accordance with FASB ASC 740, under which deferred income taxes are recognized for the future tax effects of temporary differences between the financial statement carrying amounts and the tax basis of existing assets and liabilities using the enacted statutory tax rates in effect at year-end. The effect on deferred taxes for a change in tax rates is recognized in earnings in the period that includes the enactment date. A valuation allowance for deferred tax assets is recorded when it is more likely than not that the benefit from the deferred tax asset will not be realized.
	Uncertain Income Tax Positions
	Under accounting standards for uncertainty in income taxes (ASC 740-10), a company recognizes a tax benefit in the financial statements for an uncertain tax position only if management's assessment is that the position is “more likely than not” (i.e., a likelihood greater than 50 percent) to be allowed by the tax jurisdiction based solely on the technical merits of the position. The term “tax position” in the accounting standards for income taxes refers to a position in a previously filed tax return or a position expected to be taken in a future tax return that is reflected in measuring current or deferred income tax assets and liabilities for interim or annual periods.
Loss per Common Share	'
	Loss per Common Share
	Basic net income or loss per common share is computed by dividing the net income or loss attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period. Diluted net income or loss per common share is calculated in the same manner, but also considers the impact to net income and common shares for the potential dilution from stock options, stock warrants and any outstanding convertible securities.
	The Company has issued potentially dilutive instruments in the form of our restricted common stock granted and not yet issued, common stock warrants, common stock options granted to our employees and directors, and our Series E Cumulative Convertible Preferred Stock. The Company did not include any of these instruments in its calculation of diluted loss per share during the periods because to include them would be anti-dilutive due to the Company's loss from continuing operations during the periods.
Regulated Activities	'
	Regulated Activities
	Energy Hunter Securities, Inc. is a 100%-owned subsidiary and is a registered broker-dealer and member of the Financial Industry Regulatory Authority. Among other regulatory requirements, it is subject to the net capital provisions of Rule 15c3-1 under the Securities Exchange Act of 1934, as amended. Because it does not hold customer funds or securities or owe money or securities to customers, Energy Hunter Securities, Inc. is required to maintain minimum net capital equal to the greater of $5,000 or 6.67% of its aggregate indebtedness. At December 31, 2013 and 2012, Energy Hunter Securities, Inc. had net capital of $77,953 and $71,928, respectively, and aggregate indebtedness of $16,657 and $291,307, respectively.
	Sentra Corporation, a 100%-owned subsidiary, owns and operates distribution systems for retail sales of natural gas in south central Kentucky. Sentra Corporation’s gas distribution billing rates are regulated by Kentucky’s Public Service Commission based on recovery of purchased gas costs. The Company accounts for its operations based on the provisions of ASC 980-605, Regulated Operations–Revenue Recognition, which requires covered entities to record regulatory assets and liabilities resulting from actions of regulators.
Other Comprehensive Income	'
	Other Comprehensive Income (Loss)
	The functional currency of the Company's operations in Canada (which operations are reflected in these financial statements as discontinued operations) is the Canadian dollar. For purposes of consolidation, the Company translates the assets and liabilities of its Canadian subsidiary into U.S. dollars at current exchange rates while revenues and expenses are translated at the average rates in effect for the period. The related translation gains and losses are included in accumulated other comprehensive income.

ORGANIZATION_NATURE_OF_OPERATI2

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Line Items]	'
Schedule of Inventory, Current and Noncurrent [Table Text Block]	'
	The following table sets forth the Company's inventory as of December 31, 2013 and December 31, 2012, respectively:
		2013				2012
		(in thousands)
	Materials and supplies	$	6,790			$	11,531
	Commodities	368				1,095
	Less:
	Materials included in other long term assets	—				(3,464		)
	Inventory	$	7,158			$	9,162
Schedule of Oil Natural Gas And NGL Revenue [Table Text Block]	'
	During the years ended December 31, 2013, 2012, and 2011 the Company recognized sales of oil, natural gas and NGL as follows:
		Year Ended December 31,
		2013				2012			2011
						(in thousands)
	Oil	$	140,426			$	77,172		$	37,520
	Natural gas	41,867				36,657			21,206
	NGL	15,306				830			—
	Total oil and natural gas sales	$	197,599			$	114,659		$	58,726
Geological Geophysical Costs and Leasehold Abandonments Expense [Table Text Block]	'
	The following table provides the Company's exploration expense for 2013, 2012 and 2011:
		Year Ended December 31,
		2013				2012			2011
		(in thousands)
	Geological and geophysical	$	1,402			$	2,570		$	1,497
	Leasehold impairments:
	Williston Basin	89,167				59,214			—
	Appalachian Basin	6,773				15,033			802
	South Texas	—				1,404			306
		$	97,342			$	78,221		$	2,605
Schedule of Proved Property Impairments [Table Text Block]	'
	During the years ended December 31, 2013, 2012 and 2011, the Company recorded proved property impairments as follows:
		Year Ended December 31,
		2013				2012			2011
		(in thousands)
	Williston Basin	$	8,498			$	3,631		$	—
	Appalachian Basin	1,151				76			—
	South Texas	319				65			—
		$	9,968			$	3,772		$	—
Investment [Table Text Block]	'
	Below is a summary of changes in investments for the years ended December 31, 2013 and 2012:
		Available for Sale Securities (1)				Equity Method Investments (2)			Cost Method Investments
		(in thousands)
	Fair value at December 31, 2011	$	497			$	—		$	—
	Additional cost basis from acquisition	—				3,943			1,870
	Transfers	1,770				—			(1,770		)
	Decrease in carrying amount return of capital	—				—			(100		)
	Equity in net loss recognized in other income (expense)	—				(1,333		)	—
	Impairment in carrying value of equity method investment recognized in other income (expense)	—				(538		)	—
	Change in fair value recognized in other comprehensive loss	(309		)		—			—
	Fair value at December 31, 2012	$	1,958			$	2,072		$	—
	Securities received as consideration	42,300				—			—
	Sales of securities	(50,562		)		—			—
	Realized gain recognized in net income	8,262				—			—
	Decrease in carrying amount return of capital	—				(138		)	—
	Equity in net loss recognized in other income (expense)	—				(767		)	—
	Impairment in carrying value of equity method investment recognized in other income (expense)	—				(227		)	—
	Other adjustments	(55		)		—
	Change in fair value recognized in other comprehensive loss	(84		)		—			—
	Fair value as of December 31, 2013	$	1,819			$	940		$	—
Schedule of Assets Held for Sale [Table Text Block]	'
	The following table summarizes assets held for sale for the years indicated. See "Note 2 - Divestitures and Discontinued Operations.”
		December 31,
		2013				2012
		(in thousands)
	MHP
	Current portion	$	3,495			$	—
	Long term portion	99,616				—
	Total MHP assets held for sale	$	103,111			$	—
	WHC
	Current portion	$	1,871			$	—
	Long term portion	63,071				—
	Total WHC assets held for sale	$	64,942			$	—
	Alpha Hunter Drilling
	Current portion	$	—			$	500
	Long-term portion	—				—
	Total Alpha Hunter Drilling assets held for sale	$	—			$	500
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]	'
	The following table summarizes the types of potentially dilutive securities outstanding as of December 31, 2013, 2012 and 2011:
		December 31,
		2013			2012			2011
		(in thousands of shares)
	Series E Preferred Stock	10,946			10,897			—
	Warrants	17,169			13,376			13,526
	Restricted shares granted, not yet issued	28			—			38
	Common stock options	16,891			14,847			12,566
	Total	45,034			39,120			26,130
Gas Transportation Gathering Processing and Other Equipment [Member]	'
Property, Plant and Equipment [Line Items]	'
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	'
		December 31,
		2013				2012
		(in thousands)
	Gas transportation, gathering and processing equipment and other	$	315,642			$	218,656
	Less accumulated depreciation and depletion	(26,222		)		(16,746		)
	Net capitalized costs	$	289,420			$	201,910
Oil and natural gas properties	'
Property, Plant and Equipment [Line Items]	'
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	'
	Our oil and natural gas properties comprised the following:
		December 31,
		2013				2012
		(in thousands)
	Mineral interests in properties:
	Unproved leasehold costs	$	469,337			$	645,164
	Proved leasehold costs	336,357				454,556
	Wells and related equipment and facilities	438,275				727,711
	Uncompleted wells, equipment and facilities	97,748				71,665
	Advances to operators for wells in progress	13,571				9,563
	Total costs	1,355,288				1,908,659
	Less accumulated depreciation, depletion, and amortization	(130,629		)		(186,156		)
	Net capitalized costs	$	1,224,659			$	1,722,503

DIVESTITURES_AND_DISCONTINUED_1

DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Discontinued Operations	'
	The Company included the results of operations of MHP and WHI Canada for all periods presented, Eagle Ford Hunter through April 24, 2013, and Hunter Disposal through February 17, 2012 in discontinued operations as follows:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Revenues	$	91,364		$	133,643		$	60,633
	Expenses (1)	(174,049		)	(160,127		)	(79,431		)
	Other income (expense)	6,847			3,431			1,366
	Income (loss) from discontinued operations before tax	(75,838		)	(23,053		)	(17,432		)
	Income tax benefit (expense) (2)	4,707			3,579			(2,166		)
	Income (loss) from discontinued operations, net of tax	(71,131		)	(19,474		)	(19,598		)
	Gain on disposal of discontinued operations, net of taxes (3)(4)	52,019			2,409			—
	Loss from discontinued operations, net of tax	$	(19,112	)	$	(17,065	)	$	(19,598	)
	_____________________
	-1	Includes impairment expense of $78.5 million, $324,000, and none for the years ended December 31, 2013, 2012, and 2011, respectively, and exploration expense of $19.6 million, $38.7 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively relating to the discontinued operations of MHP and WHI Canada, which is recorded in income (loss) from discontinued operations.
	-2	The Company’s effective tax rate on the loss from discontinued operations is 6.2% primarily due to the significant losses generated in WHI Canada, which has an overall lower statutory tax rate further lowered by the utilization of certain net operating losses.
	-3	Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.
	-4	The Company’s effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.

FAIR_VALUE_OF_FINANCIAL_INSTRU1

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Schedule of inputs used to calculated fair value of convertible security embedded derivative	'
	The key inputs used in the Black-Scholes option pricing model were as follows:
		31-Dec-13
	Life	3.1			years
	Risk-free interest rate	0.93			%
	Estimated volatility	40			%
	Dividend	—
	GreenHunter Resources Stock price at end of period	$	1.18
Schedule of reconciliation of derivative assets and liabilities measured at fair value using significant unobservable inputs	'
	The following table presents the changes in the fair value of the derivative assets and liabilities measured at fair value using significant unobservable inputs for the year ended December 31, 2013:
		Embedded Derivatives
		Series A Preferred Units				Convertible Security
		(in thousands)
	Fair value at December 31, 2012	$	(43,548	)		$	264
	Issued or acquired embedded derivative asset (liability)	(14,645		)		—
	Change in fair value recognized in other income (expense)	(17,741		)		(185		)
	Fair value as of December 31, 2013	$	(75,934	)		$	79
Fair value measurements on a recurring basis	'
	The following tables present financial assets and liabilities which are adjusted to fair value on a recurring basis at December 31, 2013 and 2012:
		Fair Value Measurements on a Recurring Basis
		31-Dec-13
		(in thousands)
		Level 1				Level 2				Level 3
	Available for sale securities	$	1,819			$	—			$	—
	Commodity derivative assets	—				554				—
	Convertible security derivative assets	—				—				79
	Total assets at fair value	$	1,819			$	554			$	79
	Commodity derivative liabilities	$	—			$	2,279			$	—
	Convertible preferred stock derivative liabilities	—				—				75,934
	Total liabilities at fair value	$	—			$	2,279			$	75,934
		Fair Value Measurements on a Recurring Basis
		31-Dec-12
		(in thousands)
		Level 1				Level 2				Level 3
	Available for sale securities	$	1,958			$	—			$	—
	Commodity derivative assets	—				4,882				—
	Convertible security derivative assets	—				—				264
	Total assets at fair value	$	1,958			$	4,882			$	—
	Commodity derivative liabilities	$	—			$	7,477			$	—
	Convertible preferred stock derivative liabilities	—				—				43,548
	Total liabilities at fair value	$	—			$	7,477			$	43,548
Carrying amounts and fair values of long-term debt	'
	The carrying amounts and fair values of long-term debt are as follows:
			Fair Value		31-Dec-13								31-Dec-12
			Hierarchy Level		Carrying Amount				Estimated Fair Value				Carrying Amount		Estimated Fair Value
					(in thousands)
	Senior Notes (1)		Level 2		$	597,230			$	651,300			$	597,212	$	613,500
	MHR Senior Revolving Credit Facility (2)		Level 3		218,000				218,000				225,000		225,000
	Eureka Hunter Pipeline, LLC second lien term loan (3)		Level 3		50,000				58,921				50,000		58,550
	Equipment notes payable (3)		Level 3		18,615				17,676				18,548		17,450
	________________________________
	(1) The fair value of the Company's Senior Notes is based on quoted market prices.
	(2) The carrying value of each of the MHR Senior Revolving Credit Facility and Magnum Hunter's second lien term loan approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us at such date.
	(3) The fair value of (a) Eureka Hunter Pipeline’s second lien term loan and (b) equipment note payable, is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.
Fair value measurements on a non-recurring basis	'
	New fair value measurements of proved oil and natural gas properties during the year ended December 31, 2013 and 2012 consist of:
	Fair Value Measurements on a Non-recurring Basis
			(Level 1)				(Level 2)				(Level 3)
			(in thousands)
	Proved properties impaired (1)		$	—			$	—			$	1,024
	Total during the year ended December 31, 2013		$	—			$	—			$	1,024
	Proved properties impaired (1)		$	—			$	—			$	58,082
	Acquisitions (2)		—				—				532,150
	Total during the year ended December 31, 2012		$	—			$	—			$	590,232
	________________________________
	(1) The Company recorded impairment charges from continuing operations of $10.0 million and $3.8 million during the years ended December 31, 2013 and 2012, respectively, as a result of writing down the carrying value of certain properties to fair value. In order to determine fair value, Magnum Hunter compares net capitalized costs of proved oil and natural gas properties to estimated undiscounted future net cash flows using management's expectations of economically recoverable reserves. If the net capitalized cost exceeds the undiscounted future net cash flows, Magnum Hunter impairs the net cost basis down to the discounted future net cash flows, which is management's estimate of fair value. Significant inputs used to determine the fair value include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average
	cost of capital rate. The underlying commodity prices embedded in the Company's estimated cash flows are the product of a process that begins with third party analyst forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Magnum Hunter's management believes will impact realizable prices. The inputs used by management for the fair value measurements utilized in this review include significant unobservable inputs, and therefore, the fair value measurements employed are classified as Level 3 for these types of assets.
	(2)Magnum Hunter records the fair value of assets and liabilities acquired in business combinations. During the year ended December 31, 2012, Magnum Hunter acquired oil and natural gas properties with a fair value of $532.2 million. Properties acquired are recorded at fair value, which correlates to the discounted future net cash flow. Significant inputs used to determine the fair value of proved properties include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. The underlying commodity prices embedded in the Company's estimated cash flows are the product of a process that begins with third party analyst forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Magnum Hunter's management believes will impact realizable prices. For acquired unproved properties, the market-based weighted average cost of capital rate is subjected to additional project specific risking factors. The inputs used by management for the fair value measurements of these acquired oil and natural gas properties include significant unobservable inputs, and therefore, the fair value measurements employed are classified as Level 3 for these types of assets.

FINANCIAL_INSTRUMENTS_AND_DERI1

FINANCIAL INSTRUMENTS AND DERIVATIVES (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of commondity derivatives	'
	The table below is a summary of the Company's commodity derivatives as of December 31, 2013:
					Weighted Avg
	Natural Gas	Period	MMBtu/d		Price per MMBtu
	Swaps	Jan 2014 - Dec 2014	10,000		$4.13
	Ceilings purchased (call)	Jan 2014 - Dec 2014	10,000		$6.15
	Ceilings sold (call)	Jan 2014 - Dec 2014	26,000		$5.47
	Floors purchased (put)	Jan 2014 - Dec 2014	10,000		$4.25
	Floors sold (put)	Jan 2014 - Dec 2014	10,000		$3.75
					Weighted Avg
	Crude Oil	Period	Bbl/d		Price per Bbl
	Collars (1)	Jan 2014 - Dec 2014	663		$85.00 - $91.25
		Jan 2015 - Dec 2015	259		$85.00 - $91.25
	Traditional three-way collars (2)	Jan 2014 - Dec 2014	4,000		$64.94 - $85.00 - $102.50
	Ceilings sold (call)	Jan 2015 - Dec 2015	1,570		$120.00
	Floors sold (put)	Jan 2014 - Dec 2014	663		$65.00
		Jan 2015 - Dec 2015	259		$70.00
	________________________________
	(1) A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.
	(2) These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.
Schedule of fair value of derivative contracts	'
	The following table summarizes the fair value of the Company's derivative contracts as of the dates indicated:
		Derivatives not designated as hedging instruments
		Gross Derivative Assets						Gross Derivative Liabilities
		December 31,						December 31,
		2013				2012		2013			2012
	Commodity	(in thousands)
	Derivative assets	$	529			$	4,882	$	—		$	—
	Derivatives assets, long term	25				—		—			—
	Derivative liabilities	—				—		(1,903		)	(3,501		)
	Derivative liabilities, long term	—				—		(376		)	(3,976		)
	Total commodity	$	554			$	4,882	$	(2,279	)	$	(7,477	)
	Financial
	Derivative assets	$	79			$	264	$	—		$	—
	Derivative liabilities, long term	—				—		(75,934		)	(43,548		)
	Total financial	$	79			$	264	$	(75,934	)	$	(43,548	)
	Total derivatives	633				5,146		(78,213		)	(51,025		)
Schedule of net gain (loss) on derivative contracts	'
	The following table summarizes the net gain (loss) on all derivative contracts included in other income (expense) on the consolidated statements of operations for the years ended December 31, 2013, 2012 and 2011:
		For the Year Ended December 31,
		2013				2012		2011
		(in thousands)
	Gain (loss) on settled transactions	$	(8,216	)		$	11,294	$	(2,136	)
	Gain (loss) on open transactions	(17,058		)		10,945		(4,210		)
	Total gain (loss)	$	(25,274	)		$	22,239	$	(6,346	)

ACQUISITIONS_Tables

ACQUISITIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Acquisitions	'
Summary of revenue and operating income (loss) from the acquisitions	'
	The following summarizes the revenue and operating income (loss) from the acquisitions included in the Company's consolidated statements of operations for the years ended December 31, 2013 and 2012:
		For the year ended December 31,
		2013							2012
		Revenues				Operating Income (loss)			Revenues		Operating Income (loss)
		(in thousands)							(in thousands)
	Eagle Operating assets	$	7,331			$	(26,867	)	$	5,500	$	(3,019	)
	TransTex assets	$	12,765			$	(812	)	$	7,014	$	(393	)
	Baytex Energy USA assets	$	100,572			$	(101,627	)	$	18,430	$	(6,649	)
	VIRCO acquisition	$	4,453			$	(177	)	$	1,094	$	450
Schedule of pro forma information	'
		Pro Forma
		For the Year Ended December 31,
			2012
		(in thousands except for per share amount, unaudited)
	Total revenue		$	159,085
	Operating loss		(108,177		)
	Net loss		(150,777		)
	Net loss attributable to Magnum Hunter Resources Corporation		(146,764		)
	Net loss attributable to common shareholders		$	(188,736	)
	Loss per common share, basic and diluted		$	(1.21	)
Eagle Operating, Inc.	'
Acquisitions	'
Summary of purchase price and fair value of the net assets acquired	'
	The acquisition was accounted for using the acquisition method of accounting, which requires the net assets acquired to be recorded at their fair values. The following table summarizes the purchase price and the estimates of fair values of the net assets acquired (in thousands, except shares and per share information):
	Fair value of total purchase price:
	296,859 shares of common stock issued on March 30, 2012 at $6.41 per share	$	1,902
	Cash	50,974
	Total	$	52,876
	Amounts recognized for assets acquired and liabilities assumed:
	Oil and gas properties	$	54,832
	ARO	(1,956		)
	Total	$	52,876
Trans Tex Gas Services	'
Acquisitions	'
Summary of purchase price and fair value of the net assets acquired	'
	The following table summarizes the purchase price and the estimates of fair values of the net assets acquired from TransTex (in thousands):
	Fair value of total purchase price:
	Cash	$	46,047
	Eureka Hunter Holdings Class A Common Units	12,453
	Total	$	58,500
	Amounts recognized for assets acquired and liabilities assumed:
	Working capital	$	525
	Equipment and other fixed assets	15,575
	Other assets	1,306
	Goodwill (Note 8)	30,602
	Intangible assets (Note 8)	10,492
	Total	$	58,500
Baytex	'
Acquisitions	'
Summary of purchase price and fair value of the net assets acquired	'
	The following table summarizes the purchase price and the preliminary estimates of fair values of the net assets acquired (in thousands):
	Fair value of total purchase price:
	Cash	$	312,018
	Total	$	312,018
	Amounts recognized for assets acquired and liabilities assumed:
	Oil and gas properties	$	312,294
	ARO	(276		)
	Total	$	312,018
Viking International Resources Co., Inc	'
Acquisitions	'
Summary of purchase price and fair value of the net assets acquired	'
	The following table summarizes the purchase price and the preliminary estimates of fair values of the net assets acquired (in thousands):
	Fair value of total purchase price:
	Cash	$	37,349
	2,774,850 depositary shares evidencing Series E Preferred Stock issued on November 2, 2012, valued at $23.50 per share	65,209
	Escrow settlement	(1,750		)
	Total	$	100,808
	Amounts recognized for assets acquired and liabilities assumed:
	Oil and gas properties	$	110,224
	Current assets	1,676
	Equipment and other fixed assets	970
	Accounts payable and accrued expenses	(3,928		)
	Other long-term liabilities	(2,362		)
	ARO	(5,772		)
	Total	$	100,808

GOODWILL_AND_INTANGIBLE_ASSETS1

GOODWILL AND INTANGIBLE ASSETS (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Changes in Intangible Assets	'
	The following table summarizes the Company's changes in intangible assets during the years ended December 31, 2013 and 2012:
		Amortization			December 31,			December 31,
		Period			2013			2012
					(in thousands)
	Intangible assets, at beginning of the period				$	10,492		$	—
	Additions through acquisition:
	Customer relationships	12.5	years		—			5,434
	Trademark	11	years		—			859
	Existing contracts	2.9	years		—			4,199
	Total intangible assets				10,492			10,492
	Accumulated amortization:
	Customer relationships				(1,248		)	(326		)
	Trademark				(137		)	(58		)
	Existing contracts				(2,577		)	(1,127		)
	Intangible assets, net of accumulated amortization				$	6,530		$	8,981
Schedule of Amortization of Intangible Assets Over the Next Five Years	'
	The following table summarizes the aggregate amortization of intangible assets over the next five years:
			(in thousands)
	2014		$	2,007
	2015		$	981
	2016		$	586
	2017		$	519
	2018		$	457
	Thereafter		$	1,980

ASSET_RETIREMENT_OBLIGATIONS_T

ASSET RETIREMENT OBLIGATIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Summary of asset retirement obligation	'
	The following table summarizes the changes in the Company’s ARO transactions during the years ended December 31, 2013 and 2012:
		2013			2012
		(in thousands)
	Asset retirement obligation at beginning of period	$	30,680		$	20,584
	Assumed in acquisition	17			8,027
	Liabilities incurred	253			373
	Liabilities settled	(98		)	(80		)
	Liabilities associated with assets sold	(7,614		)	—
	Accretion expense	2,264			1,671
	Revisions in estimated liabilities	1,935			76
	Reclassified as liabilities associated with assets held for sale	(11,148		)	13
	Effect of foreign currency translation	(73		)	16
	Asset retirement obligation at end of period	16,216			30,680
	Less: current portion	(53		)	(2,358		)
	Asset retirement obligation at end of period	$	16,163		$	28,322

LONGTERM_DEBT_Tables

LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Details of notes payable	'
	Notes payable at December 31, 2013 and 2012 consisted of the following:
		As of December 31,
		2013			2012
		(in thousands)
	Senior Notes Payable due May 15, 2020, interest rate of 9.75%, net of unamortized discount of $2.8 million at December 31, 2013 and 2012	$	597,230		$	597,212
	Various equipment and real estate notes payable with maturity dates February 2015 - November 2017, interest rates of 4.25% - 5.70% (1)	18,615			18,548
	Eureka Hunter Pipeline, LLC second lien term loan due August 16, 2018, interest rate of 12.5%	50,000			50,000
	MHR Senior revolving credit facility due April 13, 2016, interest rate of 3.42% at December 31, 2013 and 3.56% at December 31, 2012	218,000			225,000
		$	883,845		$	890,760
	Less: current portion	(3,967		)	(3,991		)
	Total long-term debt	$	879,878		$	886,769
	_________________
	(1) Includes notes classified as liabilities associated with assets held for sale of which $163,000 is current and $3.8 million is long term
Summary of approximate annual maturities of debt	'
	The following table presents the approximate annual maturities of debt, gross of unamortized discount:
		(in thousands)
	2014	$	3,967
	2015	7,940
	2016	224,378
	2017	330
	2018	50,000
	Thereafter	597,230
		$	883,845
Schedule of Interest Expense Incurred on Debt [Table Text Block]	'
	The following table sets forth interest expense for the years ended December 31, 2013 and 2012:
		Years Ended
		December 31,
		2013			2012
		(in thousands)
	Interest expense incurred on debt, net of amounts capitalized	$	67,605		$	44,216
	Amortization and write-off of deferred financing costs	4,818			7,400
	Total Interest Expense	$	72,423		$	51,616

SHAREBASED_COMPENSATION_Tables

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Summary of stock option and stock appreciation rights	'
	A summary of stock option and stock appreciation rights activity for the years ended December 31, 2013, 2012, and 2011 is presented below:
		2013						2012				2011
				Weighted-Average Exercise Price						Weighted-Average Exercise Price				Weighted-Average Exercise Price
		Shares						Shares				Shares
	Outstanding at beginning of period	14,846,994		$	6.01			12,566,199		$	5.64	12,779,282		$	2.65
	Granted	4,937,575		$	4.11			4,978,750		$	6	5,601,792		$	7.74
	Exercised	(1,466,025	)	$	3.66			(1,304,050	)	$	1.54	(5,479,250	)	$	0.92
	Forfeited or expired	(1,427,125	)	$	5.51			(1,393,905	)	$	7.14	(335,625	)	$	3.4
	Outstanding at end of period	16,891,419		$	5.69			14,846,994		$	6.01	12,566,199		$	5.64
	Exercisable at end of the year	9,983,743		$	5.96			8,683,622		$	5.97	6,915,471		$	4.97
Summary of non-vested options and stock appreciation rights	'
	A summary of the Company’s non-vested options and stock appreciation rights as of December 31, 2013, 2012, and 2011 is presented below:
	Non-vested Options	2013		2012			2011
	Non-vested at beginning of period	6,163,372		5,650,782			5,215,532
	Granted	4,937,575		4,978,750			5,601,792
	Vested	(3,133,700	)	(3,405,434	)		(4,832,417	)
	Forfeited	(1,059,771	)	(1,060,726	)		(334,125	)
	Non-vested at end of period	6,907,476		6,163,372			5,650,782
Assumptions used in fair value method calculation	'
	The assumptions used in the fair value method calculations for the years ended December 31, 2013, 2012, and 2011 are disclosed in the following table:
			Year Ended December 31,
			2013	2012		2011
	Weighted average fair value per option granted during the period (1)		$2.52	$3.72		$4.28
	Assumptions (2) :
	Weighted average stock price volatility (3)		80.61%	82.64%		64.29%
	Weighted average risk free rate of return		0.78%	0.77%		2.04%
	Weighted average estimated forfeiture rate (4)		2.45%	—%		—%
	Weighted average expected term		4.65 years	4.51 years		6.36 years
	(1)	Calculated using the Black-Scholes fair value based method for service and performance based grants and the Lattice Model for market based grants.
	(2)	The Company has not paid cash dividends on its common stock.
	(3)	The volatility assumption was estimated based upon a blended calculation of historical volatility and implied volatility over the life of the awards.
	(4)	For the years 2012 and 2011, the Company estimated forfeitures to be zero based on the majority of options being granted to executive officers who are less likely to forfeit shares.
Summary of non-vested shares	'
	A summary of the Company’s non-vested common shares granted under the Stock Incentive Plan as of December 31, 2013, 2012, and 2011 is presented below:
		2013						2012				2011
				Weighted-Average Share Price						Weighted-Average Share Price				Weighted-Average Share Price
	Non-vested Shares	Shares						Shares				Shares
	Non-vested at beginning of year	65,025		$	6.09			155,049		$	4.43	300,074		$	4.43
	Granted	210,494		$	4.66			69,791		$	4.29	40,305		$	5.45
	Vested	(248,019	)	$	4.75			(159,815	)	$	4.46	(185,330	)	$	0.47
	Non-vested at end of year	27,500		$	7.24			65,025		$	6.09	155,049		$	4.43

SHAREHOLDERS_EQUITY_Tables

SHAREHOLDERS' EQUITY (Tables)	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Summary of warrant activity	'
	A summary of warrant activity for the years ended December 31, 2013, 2012, and 2011 is presented below:
		2013						2012					2011
				Weighted -						Weighted -					Weighted -
				Average						Average					Average
		Shares		Exercise Price				Shares		Exercise Price			Shares		Exercise Price
	Outstanding at beginning of year	13,376,277		$	10.56			13,525,832		$	10.48		963,034		$	2.91
	Granted	17,030,622		$	8.5			—		$	—		13,391,655		$	10.56
	Exercised, forfeited, or expired	(13,237,889	)	$	10.5			(149,555	)	$	3.32		(828,857	)	$	2.97
	Outstanding at end of year	17,169,010		$	8.56			13,376,277		$	10.56		13,525,832		$	10.48
	Exercisable at end of year	17,169,010		$	8.56			13,376,277		$	10.56		13,525,832		$	10.48
Summary of non-controlling interests	'
	A summary of non-controlling interests in the Company for the years ended December 31, 2013, 2012, and 2011 is presented below:
		Year Ended December 31,
		2013				2012				2011
		(in thousands)
	Non-controlling interest at beginning of period	$	10,139			$	2,196			$	1,450
	Non-controlling interests acquired through acquisition of NGAS	—				—				497
	Purchase of outstanding non-controlling interests	—				(497		)		—
	Issuance of shares of Eureka Hunter Holdings, LLC Common Units	—				12,453				—
	Income (loss) attributable to non-controlling interest	(988		)		(4,013		)		249
	Other	(1		)		—				—
	Non-controlling interest at end of period	$	9,150			$	10,139			$	2,196
Summary of dividends paid	'
	A summary of dividends paid by the Company for the years ended December 31, 2013, 2012, and 2011 is presented below:
		Year Ended December 31,
		2013				2012				2011
		(in thousands)
	Dividend on Eureka Hunter Holdings, LLC Series A Preferred Units	$	(14,323	)		$	(8,090	)		$	—
	Dividend on Series C Preferred Stock	(10,248		)		(10,248		)		(10,248		)
	Dividend on Series D Preferred Stock	(17,655		)		(11,699		)		(3,759		)
	Dividend on Series E Preferred Stock	(7,561		)		(894		)		—
	Total dividends on Preferred Stock	$	(49,787	)		$	(30,931	)		$	(14,007	)

INCOME_TAXES_Tables

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Provision for income taxes	'
	The total provision for income taxes applicable to continuing operations consists of the following:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Deferred income tax benefit
	Federal	$	(63,629	)	$	(15,109	)	$	(1,025	)
	State	(6,668		)	(4,203		)	(1,837		)
	Total deferred tax benefit	$	(70,297	)	$	(19,312	)	$	(2,862	)
	Total income tax benefit	$	(70,297	)	$	(19,312	)	$	(2,862	)
Reconciliation of the reported amount of income tax expense (benefit) to the amount of income tax expense that would result from applying domestic federal statutory tax rates to pretax income	'
	The following is a reconciliation of the reported amount of income tax expense (benefit) attributable to continuing operations for the years ended December 31, 2013, 2012, and 2011 to the amount of income tax expense that would result from applying domestic federal statutory tax rates to pretax income:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Income tax benefit at statutory U.S. rate	$	(96,022	)	$	(48,639	)	$	(20,887	)
	State income taxes (net of federal benefit)	(4,334		)	(2,732		)	(1,194		)
	Tax effect of permanent differences	750			(555		)	419
	Tax effect of loss attributable to non-controlled interest	346			797			—
	Tax benefit recognized as tax expense in discontinued operations	(13,879		)	—			—
	Change in valuation allowance	43,232			31,810			18,800
	Other	(390		)	7			—
	Total continuing operations	(70,297		)	(19,312		)	(2,862		)
	Discontinued operations	(3,336		)	(2,283		)	2,166
	Total tax benefit	$	(73,633	)	$	(21,595	)	$	(696	)
Schedule of Income before Income Tax, Domestic and Foreign [Table Text Block]	'
	Income (loss) before income taxes was as follows:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Domestic	$	(274,349	)	$	(138,968	)	$	(59,676	)
	Loss from continuing operations	(274,349		)	(138,968		)	(59,676		)
	Loss from discontinued operations	(75,838		)	(23,053		)	(17,432		)
	Gain on disposal of discontinued operations	53,389			3,706			—
	Loss before income tax	$	(296,798	)	$	(158,315	)	$	(77,108	)
Components of deferred income taxes	'
	The tax effects of temporary differences that gave rise to the Company's deferred tax assets and liabilities are presented below:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Deferred tax assets:
	Net operating loss carry forwards	$	155,507		$	193,310		$	62,923
	Share-based compensation	10,156			7,950			10,247
	Depletion carryforwards	1,047			997			972
	Tax credits	53			53			26,340
	US investment in Canada	74,148			—			—
	Other	561			532			7,475
	Deferred tax liabilities:
	Property and equipment	(90,950		)	(206,650		)	(111,015		)
	Valuation allowance	(150,522		)	(70,450		)	(92,241		)
	Net deferred tax asset (liability)	$	—		$	(74,258	)	$	(95,299	)
Reconciliation of unrecognized tax benefits	'
	Following is a reconciliation of the total amounts of unrecognized tax benefits during the years ended December 31, 2013, 2012 and 2011:
		Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Unrecognized tax benefits at January 1	$	3,879		$	—		$	—
	Change in unrecognized tax benefits taken during a prior period	—			—			—
	Change in unrecognized tax benefits taken during the current period (netted against the US net operating loss)	—			3,879			—
	Decreases in unrecognized tax benefits from settlements with taxing authorities	—			—			—
	Reductions to unrecognized tax benefits from lapse of statutes of limitations	—			—			—
	Unrecognized tax benefits at December 31	$	3,879		$	3,879		$	—

MAJOR_CUSTOMERS_Tables

MAJOR CUSTOMERS (Tables)	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
Schedule of percentages of the consolidated oil, NGL and gas revenues represented by major purchasers	'
	The table below provides the percentages of the Company's consolidated oil, NGL and gas revenues from continuing operations represented by its major purchasers during the periods presented:
		Year Ended December 31,
		2013		2012		2011
	Samson Resources Company	36	%	17	%	10	%
	Baytex Energy USA LTD	10	%	15	%	3	%
	Teneska Marketing Ventures	9	%	14	%	14	%
	South Jersey	5	%	14	%	10	%
	Plains Marketing, LP	4	%	11	%	16	%
	Clearfield Energy	1	%	7	%	16	%
	Ergon Oil	3	%	5	%	13	%

SUPPLEMENTAL_CASH_FLOW_INFORMA1

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Elements [Abstract]	'
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	'
	The following summarizes cash paid (received) for interest and income taxes, as well as non-cash investing transactions:
		Year Ended December 31,
		2013			2012		2011
		(in thousands)
	Cash paid for interest	$	70,366		$	40,069	$	7,952
	Cash paid for taxes	$	1,200		$	—	$	—
	Non-cash transactions
	Change in accrued capital expenditures - increase (decrease)	$	(65,634	)	$	34,621	$	81,136
	Eureka Hunter Holdings, LLC Series A convertible preferred unit dividends paid in kind	$	8,243		$	1,658	$	—
	Non-cash additions to asset retirement obligation	$	2,132		$	8,492	$	12,628
	Common stock issued for 401k matching contributions	$	1,192		$	874	$	—
	Preferred stock issued for acquisitions	$	—		$	64,968	$	—
	Eureka Hunter Holdings, LLC Class A common units issued for an acquisition	$	—		$	12,453	$	—
	Non-cash consideration received from sale of assets	$	42,300		$	7,120	$	—
	Common stock issued for acquisitions	$	—		$	1,902	$	345,537
	Debt assumed in acquisitions	$	—		$	—	$	71,895
	Exchangeable common stock issued for acquisition of NuLoch Resources	$	—		$	—	$	31,642
	Common stock issued for payment of services	$	—		$	—	$	779
	Dividends on MHR Exchangeco Corporation's exchangeable common stock in the form of 378,174 warrants with fair market value of $197 thousand	$	—		$	—	$	197

OTHER_INFORMATION_Tables

OTHER INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2013
Other Information	'
Details of unaudited summary financial results	'
	The following tables set forth unaudited summary financial results on a quarterly basis for the most recent two years.
		Quarter Ended
		March 31,			June 30,			September 30,			December 31,			Year Ended
		2013
		(in thousands)
	Total revenue	$	54,235		$	67,907		$	73,032		$	85,237		$	280,411
	Operating gain (loss) (1)	$	(40,009	)	$	(26,240	)	$	(92,676	)	$	(25,839	)	$	(184,764	)
	Income (loss) from continuing operations	$	(61,544	)	$	347		$	(132,598	)	$	(10,257	)	$	(204,052	)
	Income (loss) from discontinued operations, net of tax (2)	$	16,845		$	(7,746	)	$	(80,554	)	$	324		$	(71,131	)
	Gain (loss) on disposal of discontinued operations, net of tax (3)	$	—		$	172,452		$	(84,454	)	$	(35,979	)	$	52,019
	Net income (loss) attributable to Magnum Hunter Resources Corporation	$	(44,197	)	$	165,440		$	(296,882	)	$	(46,537	)	$	(222,176	)
	Net income (loss) attributable to common shareholders	$	(57,685	)	$	151,311		$	(311,299	)	$	(61,208	)	$	(278,881	)
	Basic and diluted income (loss) from continuing operations per common share	$	(0.36	)	$	0		$	(0.86	)	$	(0.06	)	$	(1.53	)
	Basic and diluted income (loss) per common share	$	(0.34	)	$	0.89		$	(1.83	)	$	(1.11	)	$	(1.64	)
		2012
	Total revenue	$	27,945		$	30,598		$	36,381		$	45,432		$	140,356
	Operating loss (4)	$	(15,698	)	$	(15,797	)	$	(8,898	)	$	(67,814	)	$	(108,207	)
	Loss from continuing operations	$	(22,533	)	$	(8,638	)	$	(31,313	)	$	(57,172	)	$	(119,656	)
	Income (loss) from discontinued operations, net of tax	$	5,723		$	(1,789	)	$	(1,102	)	$	(22,306	)	$	(19,474	)
	Gain (loss) on disposal of discontinued operations, net of tax	4,325			(2,101		)	—			185			2,409
	Net income (loss) attributable to Magnum Hunter Resources Corporation	$	(12,458	)	$	(12,577	)	$	(32,463	)	$	(75,210	)	$	(132,708	)
	Net loss attributable to common shareholders	$	(17,052	)	$	(20,843	)	$	(42,283	)	$	(87,236	)	$	(167,414	)
	Basic and diluted loss from continuing operations per common share	$	(0.17	)	$	(0.06	)	$	(0.19	)	$	(0.34	)	$	(0.96	)
	Basic and diluted income (loss) per common share	$	(0.13	)	$	(0.15	)	$	(0.25	)	$	(0.54	)	$	(1.07	)
	______________
	(1)	The quarter-ended September 30, 2013, loss from operations was primarily driven by the loss on the sale of certain properties in Burke County, North Dakota of $38.1 million, and exploration expense. Management reviews leasehold acreage on a quarterly basis. During the quarter-ended September 30, 2013, management determined a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return.
	(2)	The quarter-ended September 30, 2013, loss from discontinued operations was primarily driven by impairment expense of $72.5 million, as management determined a significant portion of the non-core acreage would not be utilized.
	(3)	The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".
	(4)	The quarter-ended December 31, 2012, loss from operations was primarily driven by exploration expense. During the quarter-ended December 31, 2012 management determined that a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return in 2013.
Details of operating activities by segment	'
	The following tables set forth operating activities and capital expenditures by segment for the years ended, and segment assets as of December 31, 2013, 2012, and 2011.
		For the Year Ended December 31, 2013 (in thousands)
		U.S. Upstream				Canadian Upstream				Midstream				Oil Field Services			Corporate Unallocated			Intersegment Eliminations			Total
	Oil and gas sales	$	197,599			$	—			$	—			$	—		$	—		$	—		$	197,599
	Gas transportation, gathering and processing	2				—				69,306				—			—			(8,676		)	60,632
	Oil field services	23				—				—				21,525			—			(3,117		)	18,431
	Other revenue	3,747				—				—				2			—			—			3,749
	Total revenue	201,371				—				69,306				21,527			—			(11,793		)	280,411
	Lease operating expenses	62,675				—				—				—			—			(8,714		)	53,961
	Severance taxes and marketing	17,721				—				—				—			—			—			17,721
	Exploration	97,342				—				—				—			—			—			97,342
	Gas transportation, gathering and processing	2				—				52,097				—			—			—			52,099
	Oil field services	(10		)		—				—				17,914			—			(3,079		)	14,825
	Impairment of proved oil and gas properties	9,968				—				—				—			—			—			9,968
	Depreciation, depletion, and accretion	84,526				—				12,318				2,354			—			—			99,198
	Loss on sale of assets	44,642				—				8				4			—			—			44,654
	General and administrative	14,255				—				8,400				1,338			49,241			2,173			75,407
	Total expenses	331,121				—				72,823				21,610			49,241			(9,620		)	465,175
	Operating income (loss)	(129,750		)		—				(3,517		)		(83		)	(49,241		)	(2,173		)	(184,764		)
	Interest income	219				—				—				—			4,824			(4,823		)	220
	Interest expense	(7,208		)		—				(4,351		)		(507		)	(67,420		)	7,063			(72,423		)
	Loss on derivative contracts	(185		)		—				(17,742		)		—			(7,347		)	—			(25,274		)
	Other	(340		)		—				(265		)		—			8,497			—			7,892
	Total other income (expense)	(7,514		)		—				(22,358		)		(507		)	(61,446		)	2,240			(89,585		)
	Income (loss) from continuing operations before income tax	(137,264		)		—				(25,875		)		(590		)	(110,687		)	67			(274,349		)
	Income tax benefit (expense)	41,308				—				—				—			28,989			—			70,297
	Income (loss) from continuing operations	(95,956		)		—				(25,875		)		(590		)	(81,698		)	67			(204,052		)
	Income (loss) from discontinued operations	5,293				(76,355		)		—				—						(69		)	(71,131		)
	Gain (loss) on disposal of discontinued operations	125,871				(73,852		)		—				—			—			—			52,019
	Net income (loss)	35,208				(150,207		)		(25,875		)		(590		)	(81,698		)	(2		)	(223,164		)
	Loss (income) attributable to non-controlling interest	—				—				—				—						988			988
	Net income (loss) attributable to Magnum Hunter Resources Corporation	$	35,208			$	(150,207	)		$	(25,875	)		$	(590	)	$	(81,698	)	$	986		$	(222,176	)
	Dividends on preferred stock	—				—				(21,241		)		—			(35,464		)	—			(56,705		)
	Net income (loss) attributable to common shareholders	$	35,208			$	(150,207	)		$	(47,116	)		$	(590	)	$	(117,162	)	$	986		$	(278,881	)
	Total segment assets	$	1,373,041			$	68,367			$	296,739			$	44,193		$	77,684		$	(3,373	)	$	1,856,651
	Segment capital expenditures	$	489,702			$	31,025			$	87,048			$	22,699		$	1,037		$	—		$	631,511
		For the Year Ended December 31, 2012 (in thousands)
		U.S. Upstream				Canadian Upstream				Midstream				Oil Field Services			Corporate Unallocated			Intersegment Eliminations			Total
	Oil and gas sales	$	114,659			$	—			$	—			$	—		$	—		$	—		$	114,659
	Gas transportation, gathering and processing	—				—				15,469				—			—			(2,429		)	13,040
	Oil field services	—				—				—				13,552			—			(1,219		)	12,333
	Other revenue	99				—				223				—			—			2			324
	Total revenue	114,758				—				15,692				13,552			—			(3,646		)	140,356
	Lease operating expenses	30,429				—				—				—			—			(3,590		)	26,839
	Severance taxes and marketing	7,854				—				—				—			—			—			7,854
	Exploration	78,221				—				—				—			—			—			78,221
	Gas transportation, gathering and processing	—				—				7,908				—			—			120			8,028
	Oil field services	—				—				—				10,420			—			(383		)	10,037
	Impairment of proved oil and gas properties	3,772				—				—				—			—			—			3,772
	Depreciation, depletion, and accretion	52,332				—				5,963				967			—			468			59,730
	Loss (gain) on sale of assets	278				—				(250		)		600			—			—			628
	General and administrative	21,789				—				3,798				418			27,137			312			53,454
	Total expenses	194,675				—				17,419				12,405			27,137			(3,073		)	248,563
	Operating income (loss)	(79,917		)		—				(1,727		)		1,147			(27,137		)	(573		)	(108,207		)
	Interest income	197				—				—				—			3,483			(3,481		)	199
	Interest expense	(13,053		)		—				(758		)		(327		)	(41,022		)	3,544			(51,616		)
	Loss on derivative contracts	129				—				8,692				—			13,418			—			22,239
	Other	(882		)		—				(546		)		(155		)	—			—			(1,583		)
	Total other income (expense)	(13,609		)		—				7,388				(482		)	(24,121		)	63			(30,761		)
	Income (loss) from continuing operations before income tax	(93,526		)		—				5,661				665			(51,258		)	(510		)	(138,968		)
	Income tax benefit (expense)	19,312				—				—				—			—			—			19,312
	Income (loss) from continuing operations	(74,214		)		—				5,661				665			(51,258		)	(510		)	(119,656		)
	Income (loss) from discontinued operations	6,661				(25,021		)		—				230			—			(1,344		)	(19,474		)
Gain on disposal of discontinued operations	2,409				—				—				—			—			—			2,409
Net income (loss)	(65,144		)		(25,021		)		5,661				895			(51,258		)	(1,854		)	(136,721		)
Net income (loss) attributable to non-controlling interest	4,173				—				(160		)		—			—			—			4,013
Net income (loss) attributable to Magnum Hunter Resources Corporation	(60,971		)		(25,021		)		5,501				895			(51,258		)	(1,854		)	(132,708		)
Dividends on preferred stock	—				—				(11,864		)		—			(22,842		)	—			(34,706		)
Net income (loss) attributable to common shareholders	$	(60,971	)		$	(25,021	)		$	(6,363	)		$	895		$	(74,100	)	$	(1,854	)	$	(167,414	)
Total segment assets	$	1,602,022			$	392,918			$	245,207			$	23,810		$	93,612		$	(158,937	)	$	2,198,632
Segment capital expenditures	$	417,431			$	84,536			$	57,010			$	8,828		$	805		$	—		$	568,610
	For the Year Ended December 31, 2011(in thousands)
	U.S. Upstream				Canadian Upstream				Midstream				Oil Field Services			Corporate Unallocated			Intersegment Eliminations			Total
Oil and gas sales	$	58,726			$	—			$	—			$	—		$	—		$	—		$	58,726
Gas transportation, gathering and processing	—				—				1,978				—			—			(1,484		)	494
Oil field services	—				—				—				9,417			—			(2,268		)	7,149
Other revenue	65				—				12				9			—			—			86
Total revenue	58,791				—				1,990				9,426			—			(3,752		)	66,455
Lease operating expenses	17,194				—				—				—			—			(2,196		)	14,998
Severance taxes and marketing	5,341				—				—				—			—			—			5,341
Exploration	2,605				—				—				—			—			—			2,605
Gas transportation, gathering and processing	—				—				373				—			—			—			373
Oil field services	—				—				—				8,315			—			(1,556		)	6,759
Impairment of proved oil and gas properties	—				—				—				—			—			—			—
Depreciation, depletion, and accretion	20,913				—				1,789				544			—			—			23,246
Loss (gain) on sale of assets	861				—				(500		)		—			—			—			361
General and administrative	2,255				—				850				461			50,794			—			54,360
Total expenses	49,169				—				2,512				9,320			50,794			(3,752		)	108,043
Operating income (loss)	9,622				—				(522		)		106			(50,794		)	—			(41,588		)
Interest income	6				—				—				—			4						10
Interest expense	(2,071		)		—				(1,673		)		(183		)	(9,879		)	2,054			(11,752		)
Gain (loss) on derivative contracts	—				—				—				—			(6,346		)	—			(6,346		)
Other	—				—				—				—			—			—			—
Total other expense	(2,065		)		—				(1,673		)		(183		)	(16,221		)	2,054			(18,088		)
Income (loss) from continuing operations before income tax	7,557				—				(2,195		)		(77		)	(67,015		)	2,054			(59,676		)
Income tax benefit	1,637				697				—				1,042			—			(514		)	2,862
Income (loss) from continuing operations	9,194				697				(2,195		)		965			(67,015		)	1,540			(56,814		)
Income (loss) from discontinued operations	(21,848		)		1,855				—				1,935			—			(1,540		)	(19,598		)
Gain on disposal of discontinued operations	—				—				—				—			—			—			—
Net income (loss)	(12,654		)		2,552				(2,195		)		2,900			(67,015		)	—			(76,412		)
Net loss attributable to non-controlling interest	(249		)		—				—				—			—			—			(249		)
Net income (loss) attributable to Magnum Hunter Resources Corporation	(12,903		)		2,552				(2,195		)		2,900			(67,015		)	—			(76,661		)
Dividends on preferred stock	—				—				—				—			(14,007		)	—			(14,007		)
Net income (loss) attributable to common shareholders	(12,903		)		2,552				(2,195		)		2,900			(81,022		)	—			(90,668		)
Total segment assets	$	797,674			$	349,410			$	83,847			$	17,045		$	47,839		$	(127,055	)	$	1,168,760
Segment capital expenditures	$	202,818			$	18,493			$	54,748			$	6,494		$	9,389		$	—		$	291,942
Summary of costs incurred in oil and gas property acquisition, exploration, and development activities	'
	he following table sets forth the costs incurred in oil and gas property acquisition, exploration, and development activities (in thousands):
		For the Year Ended December 31,
		2013				2012				2011
	Purchase of non-producing leases	$	149,592			$	414,037			$	397,947
	Purchase of producing properties	1,358				159,290				226,634
	Exploration costs	11,531				165,789				112,606
	Development costs	273,944				262,486				101,151
	Asset retirement obligation	2,186				407				5,390
		$	438,611			$	1,002,009			$	843,728
Summary of estimating quantities of proved reserves data	'
	he following reserve data only represent estimates and should not be construed as being exact.
	Total Proved Reserves		Crude Oil  and Liquids			Natural Gas
			(MBbl)			(MMcf)
	Balance December 31, 2010		6,824			39,452
	Revisions of previous estimates		6,937			40,494
	Purchases of reserves in place		6,345			43,757
	Extensions, discoveries, and other additions		2,687			22,399
	Sales of reserves in place		-215			-11
	Production		-869			-6,854
	Balance December 31, 2011		21,709			139,237
	Revisions of previous estimates		12,568			25,644
	Purchases of reserves in place		10,613			12,082
	Extensions, discoveries, and other additions		3,415			544
	Sales of reserves in place		-10			-63
	Production		-2,343			-14,824
	Balance December 31, 2012		45,952			162,620
	Extensions, discoveries and other additions		648			1,285
	Revisions of previous estimates		6,148			100,456
	Purchases of reserves in place		—			88
	Sales of reserves in place		-15,204			-4,185
	Production		-2,787			-13,482
	Balance December 31, 2013		34,757			246,782
	Developed reserves, included above:
	December 31, 2011		9,179			90,198
	December 31, 2012		22,617			125,526
	December 31, 2013		19,075			176,585
	Proved undeveloped reserves, included above:
	31-Dec-11		12,531			49,039
	31-Dec-12		23,335			37,094
	31-Dec-13		15,682			70,197
Details of standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves	'
	he standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:
			Years Ended December 31,
			2013				2012				2011
			(in thousands)
	Future cash inflows		$	3,711,260			$	4,248,384			$	2,409,249
	Future production costs		(1,423,306		)		(1,520,260		)		(765,048		)
	Future development costs		(421,797		)		(603,809		)		(330,007		)
	Future income tax expense		(149,367		)		(230,500		)		(253,721		)
	Future net cash flows		1,716,790				1,893,815				1,060,473
	10% annual discount for estimated timing of cash flows		(872,280		)		(1,046,162		)		(586,077		)
	Standardized measure of discounted future net cash flows		$	844,510			$	847,653			$	474,396
Changes in standardized measure of discounted future net cash flow relating to proved oil and gas reserves	'
	he changes in the standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:
			Years Ended December 31,
			2013				2012				2011
			(in thousands)
	Balance, beginning of period		$	847,653			$	474,396			$	127,959
	Net changes in prices and production costs		(7,355		)		13,647				49,498
	Changes in estimated future development costs		(261,591		)		(391,318		)		(167,399		)
	Sales and transfers of oil and gas produced during the period		(190,151		)		(179,384		)		(71,724		)
	Net changes due to extensions, discoveries, and improved recovery		12,829				60,468				110,316
	Net changes due to revisions of previous quantity estimates (1)		341,003				290,500				235,163
	Previously estimated development costs incurred during the period		283,736				245,168				24,740
	Accretion of discount		90,153				85,377				27,029
	Purchase of minerals in place		218				217,791				234,336
	Sale of minerals in place		(236,885		)		(354		)		(3,726		)
	Changes in timing and other (2)		(91,088		)		22,436				824
	Net change in income taxes		55,988				8,926				(92,620		)
	Standardized measure of discounted future net cash flows		$	844,510			$	847,653			$	474,396
	______________
	(1)	The Company's net changes due to revisions of previous quantity estimates primarily reflect upward revisions to recoverable quantities of oil and gas minerals assuming existing prices and technology. For the year ended December 31, 2013, the Company made upward revisions of 6,148 MBbl of oil and natural gas liquids and 100,456 MMcf of natural gas due to additional information gathered from continued production from the shale areas and increases in estimated ultimate recoveries (EURs). For the year ended December 31, 2012, the Company made upward revisions of 12,568 MBbls of oil and natural gas liquids and 25,644 MMcf of natural gas.
	(2)	The Company's changes in timing and other primarily represent changes in the Company's estimates of when proved reserve quantities will be realized. The reserves as of December 31, 2012, reflect accelerated recovery of minerals due to purchases of minerals in place and capital expenditures incurred to develop properties.
Standardized measure to calculate future net revenues	'
	he commodity prices inclusive of adjustments for quality and location used in determining future net revenues related to the standardized measure calculation are as follows:
			2013				2012				2011
	Oil (per Bbl)		$	93.13			$	88.37			$	96.19
	Natural gas liquids (per Bbl)		$	43.79			$	53.94			$	44.25
	Gas (per Mcf)		$	4.14			$	3.08			$	4.11

RELATED_PARTY_TRANSACTIONS_REL

RELATED PARTY TRANSACTIONS RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Schedule of Related Party Transactions [Table Text Block]	'
	The following table sets forth the related party balances as of December 31, 2013 and 2012:
		As of December 31,
		2013				2012
		(in thousands)
	Green Hunter (1)
	Accounts receivable - net	$	23			$	—
	Derivative assets (2)	$	79			$	264
	Investments (2)	$	2,262			$	3,009
	Notes receivable (2)	$	1,768			$	2,173
	Prepaid expenses	$	9			$	—
	The following table sets forth the related party transaction activities for the years ended December 31, 2013, 2012 and 2011:
				Years Ended
				December 31,
				2013				2012		2011
				(in thousands)
	GreenHunter
		Salt water disposal expense (1)		$	3,033			$	2,400	$	—
		Equipment rental expense (1)		$	282			$	1,000	$	1,300
		Office space rental expense (1)		$	13			—		—
		Professional services income (1)		$	—			$	—	$	162
		Interest income from note receivable (2)		$	205			$	191	$	—
		Dividends received from Series C shares		$	220			$	—	$	—
		Loss on investments (2)		$	730			1,333		$	—
	Pilatus Hunter, LLC
		Airplane rental expense (3)		$	166			$	174	$	463
	Executive of the Company
		Corporate apartment rental expense (4)		$	—			$	23	$	36
	_________________________________
	(1)	GreenHunter is an entity of which Gary C. Evans, Magnum Hunter's Chairman and CEO, is the Chairman, a major shareholder and former interim CEO; of which David Krueger, the Company's former Chief Accounting Officer and Senior Vice President, is the former Chief Financial Officer; and of which Ronald D. Ormand, the Company’s former Chief Financial Officer and Executive Vice President, is a former director. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources, Inc. ("Virco"), 100% owned subsidiaries of the Company, receive services related to salt water disposal and rental equipment from GreenHunter and its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services.
	(2)	On February 17, 2012, the Company sold its 100% owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a 100% owned subsidiary of GreenHunter.  The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. The Company has recorded interest income at the rate of 10% on the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and other long term assets and an available for sale investment in GreenHunter included in investments.
	(3)	The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense.
	(4)	During the years ended December 31, 2011 and 2012, the Company paid rent under a lease for a Houston, Texas corporate apartment from an executive of the Company, which apartment was used by other Company employees when in Houston for Company business.  The lease terminated in May 2012.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of future minimum lease commitments under noncancellable operating leases	'
	Future minimum lease commitments under noncancellable operating leases at December 31, 2013, are as follows (in thousands):
	2014	$	504
	2015	$	457
	2016	$	239
	2017	$	121
	2018	$	127
	Thereafter	$	53
Schedule of future minimum gathering, processing, and transportation commitments	'
	Future minimum gathering, processing, and transportation commitments at December 31, 2013, are as follows (in thousands):
	2014	$	4,332
	2015	$	4,319
	2016	$	3,373
	2017	$	2,958
	2018	$	2,947
	Thereafter	$	10,722

CONDENSED_CONSOLIDATING_GUARAN1

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Securities Under Universal Shelf Registration Statement Form S-3	'
CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	'
Schedule of condensed consolidating balance sheets	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
			As of December 31, 2013
			Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries								Resources
			Corporation																Corporation
																			Consolidated
	ASSETS
	Current assets		$	53,161			$	28,825			$	42,112			$	(3,372	)		$	120,726
	Intercompany accounts receivable		965,138				—				—				(965,138		)		—
	Property and equipment (using successful efforts accounting)		7,214				1,124,637				382,228				—				1,514,079
	Investment in subsidiaries		372,236				102,314				—				(474,550		)		—
	Other assets		17,308				100,327				104,211				—				221,846
	Total Assets		$	1,415,057			$	1,356,103			$	528,551			$	(1,443,060	)		$	1,856,651
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities		$	54,826			$	86,115			$	46,334			$	(3,410	)		$	183,865
	Intercompany accounts payable		—				896,242				68,861				(965,103		)		—
	Long-term liabilities		818,651				23,115				143,615				—				985,381
	Redeemable preferred stock		100,000				—				136,675				—				236,675
	Shareholders' equity		441,580				350,631				133,066				(474,547		)		450,730
	Total Liabilities and Shareholders' Equity		$	1,415,057			$	1,356,103			$	528,551			$	(1,443,060	)		$	1,856,651
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
			As of December 31, 2012
			Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries								Resources
			Corporation																Corporation
																			Consolidated
	ASSETS
	Current assets		$	63,167			$	48,320			$	124,041			$	(31,209	)		$	204,319
	Intercompany accounts receivable		803,834				—				—				(803,834		)		—
	Property and equipment (using successful efforts accounting)		9,596				1,148,714				766,103				—				1,924,413
	Investment in subsidiaries		763,856				101,342				102,354				(967,552		)		—
	Other assets		20,849				5,341				43,710				—				69,900
	Total Assets		$	1,661,302			$	1,303,717			$	1,036,208			$	(1,802,595	)		$	2,198,632
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities		$	28,503			$	109,536			$	135,994			$	(30,377	)		$	243,656
	Intercompany accounts payable		—				611,932				191,902				(803,834		)		—
	Long-term liabilities		831,286				83,192				127,968				—				1,042,446
	Redeemable preferred stock		100,000				—				100,878				—				200,878
	Shareholders' equity		701,513				499,057				479,466				(968,384		)		711,652
	Total Liabilities and Shareholders' Equity		$	1,661,302			$	1,303,717			$	1,036,208			$	(1,802,595	)		$	2,198,632
Schedule of condensed consolidating statements of operations	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
			For the Year Ended December 31, 2013
			Magnum Hunter				Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries (1)								Resources
			Corporation																Corporation
																			Consolidated
	Revenues		$	2,629			$	187,095			$	95,286			$	(4,599	)		$	280,411
	Expenses		112,754				326,355				125,786				(10,135		)		554,760
	Loss from continuing operations before equity in net income of subsidiaries		(110,125		)		(139,260		)		(30,500		)		5,536				(274,349		)
	Equity in net income of subsidiaries		(298,775		)		(424		)		—				299,199				—
	Loss from continuing operations before income tax		(408,900		)		(139,684		)		(30,500		)		304,735				(274,349		)
	Income tax benefit		28,989				41,315				(7		)		—				70,297
	Loss from continuing operations		(379,911		)		(98,369		)		(30,507		)		304,735				(204,052		)
	Income from discontinued operations, net of tax		(7,813		)		13,101				(78,025		)		1,606				(71,131		)
	Gain on disposal of discontinued operations, net of tax		144,378				(18,507		)		(66,707		)		(7,145		)		52,019
	Net income (loss)		(243,346		)		(103,775		)		(175,239		)		299,196				(223,164		)
	Net loss attributable to non-controlling interest		—				—				—				988				988
	Net loss attributable to Magnum Hunter Resources Corporation		(243,346		)		(103,775		)		(175,239		)		300,184				(222,176		)
	Dividends on preferred stock		(35,464		)		—				(21,241		)		—				(56,705		)
	Net income (loss) attributable to common shareholders		$	(278,810	)		$	(103,775	)		$	(196,480	)		$	300,184			$	(278,881	)
			For the Year Ended December 31, 2012
			Magnum Hunter				Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries (1)								Resources
			Corporation																Corporation
																			Consolidated
	Revenues		$	729			$	103,605			$	32,054			$	3,968			$	140,356
	Expenses		54,047				159,603				49,597				16,077				279,324
	Loss from continuing operations before equity in net income of subsidiaries		(53,318		)		(55,998		)		(17,543		)		(12,109		)		(138,968		)
	Equity in net income of subsidiaries		(97,191		)		458				(23,362		)		120,095				—
	Loss from continuing operations before income tax		(150,509		)		(55,540		)		(40,905		)		107,986				(138,968		)
	Income tax benefit		5,937				13,375				—				—				19,312
	Loss from continuing operations		(144,572		)		(42,165		)		(40,905		)		107,986				(119,656		)
	Income from discontinued operations, net of tax		—				(11,036		)		(18,695		)		10,257				(19,474		)
	Gain on disposal of discontinued operations, net of tax		—				2,409				—				—				2,409
	Net income (loss)		(144,572		)		(50,792		)		(59,600		)		118,243				(136,721		)
	Net income attributable to non-controlling interest		—				—				—				4,013				4,013
	Net loss attributable to Magnum Hunter Resources Corporation		(144,572		)		(50,792		)		(59,600		)		122,256				(132,708		)
	Dividends on preferred stock		(22,842		)		—				(11,864		)		—				(34,706		)
	Net income (loss) attributable to common shareholders		$	(167,414	)		$	(50,792	)		$	(71,464	)		$	122,256			$	(167,414	)
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
			For the Year Ended December 31, 2011
			Magnum Hunter				Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries (1)								Resources
			Corporation																Corporation
																			Consolidated
	Revenues		$	1,071			$	45,119			$	15,329			$	4,936			$	66,455
	Expenses		68,772				39,226				16,949				1,184				126,131
	Loss from continuing operations before equity in net income of subsidiaries		(67,701		)		5,893				(1,620		)		3,752				(59,676		)
	Equity in net income of subsidiaries		(5,208		)		(2,196		)		(939		)		8,343				—
	Loss from continuing operations before income tax		(72,909		)		3,697				(2,559		)		12,095				(59,676		)
	Income tax benefit		—				3,727				(351		)		(514		)		2,862
	Loss from continuing operations		(72,909		)		7,424				(2,910		)		11,581				(56,814		)
	Income from discontinued operations, net of tax		—				(30,374		)		14,014				(3,238		)		(19,598		)
	Gain on disposal of discontinued operations, net of tax		—				—				—				—				—
	Net income (loss)		(72,909		)		(22,950		)		11,104				8,343				(76,412		)
	Net income attributable to non-controlling interest		—				—				—				(249		)		(249		)
	Net loss attributable to Magnum Hunter Resources Corporation		(72,909		)		(22,950		)		11,104				8,094				(76,661		)
	Dividends on preferred stock		(14,007		)		—				—				—				(14,007		)
	Net income (loss) attributable to common shareholders		$	(86,916	)		$	(22,950	)		$	11,104			$	8,094			$	(90,668	)
Schedule of condensed consolidating statements of comprehensive income (loss)	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Comprehensive Income (Loss)
	(in thousands)
		For the Year Ended December 31, 2013
		Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter Resources
		Resources				Subsidiaries				Subsidiaries								Corporation
		Corporation																Consolidated
	Net income (loss)	$	(243,346	)		$	(103,775	)		$	(175,239	)		$	299,196			$	(223,164	)
	Foreign currency translation loss	—				—				(10,928		)		—				(10,928		)
	Unrealized gain (loss) on available for sale securities	8,262				(84		)		—				—				8,178
	Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	(8,262		)		—				—				—				(8,262		)
	Comprehensive income (loss)	(243,346		)		(103,859		)		(186,167		)		299,196				(234,176		)
	Comprehensive income loss attributable to non-controlling interest	—				—				—				988				988
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(243,346	)		$	(103,859	)		$	(186,167	)		$	300,184			$	(233,188	)
		For the Year Ended December 31, 2012
		Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter Resources
		Resources				Subsidiaries				Subsidiaries								Corporation
		Corporation																Consolidated
	Net income (loss)	$	(144,572	)		$	(50,792	)		$	(59,600	)		$	118,243			$	(136,721	)
	Foreign currency translation loss	—				—				3,883				—				3,883
	Unrealized gain (loss) on available for sale securities	—				(309		)		—				—				(309		)
	Comprehensive income (loss)	(144,572		)		(51,101		)		(55,717		)		118,243				(133,147		)
	Comprehensive (income) loss attributable to non-controlling interest	—				—				—				4,013				4,013
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(144,572	)		$	(51,101	)		$	(55,717	)		$	122,256			$	(129,134	)
		For the Year Ended December 31, 2011
		Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter Resources
		Resources				Subsidiaries				Subsidiaries								Corporation
		Corporation																Consolidated
	Net income (loss)	$	(72,909	)		$	(22,950	)		$	11,104			$	8,343			$	(76,412	)
	Foreign currency translation loss	—				—				(12,477		)		—				(12,477		)
	Unrealized gain (loss) on available for sale securities	—				14				—				—				14
	Comprehensive income (loss)	(72,909		)		(22,936		)		(1,373		)		8,343				(88,875		)
	Comprehensive (income) loss attributable to non-controlling interest	—				—				—				(249		)		(249		)
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(72,909	)		$	(22,936	)		$	(1,373	)		$	8,094			$	(89,124	)
Schedule of condensed consolidating statements of cash flows	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Cash Flows
	(in thousands)
			For the Year Ended December 31, 2013
			Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries								Resources
			Corporation																Corporation
																			Consolidated
	Cash flow from operating activities		$	(371,351	)		$	376,129			$	106,933			$	—			$	111,711
	Cash flow from investing activities		422,303				(387,660		)		(162,503		)		—				(127,860		)
	Cash flow from financing activities		(29,929		)		(946		)		31,531				—				656
	Effect of exchange rate changes on cash		—				—				(417		)		—				(417		)
	Net increase (decrease) in cash		21,023				(12,477		)		(24,456		)		—				(15,910		)
	Cash at beginning of period		26,872				(4,462		)		35,213				—				57,623
	Cash at end of period		$	47,895			$	(16,939	)		$	10,757			$	—			$	41,713
			For the Year Ended December 31, 2012
			Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries								Resources
			Corporation																Corporation
																			Consolidated
	Cash flow from operating activities		$	(458,921	)		$	275,914			$	241,018			$	—			$	58,011
	Cash flow from investing activities		(364,045		)		(277,965		)		(367,197		)		—				(1,009,207		)
	Cash flow from financing activities		831,080				(1,966		)		167,328				—				996,442
	Effect of exchange rate changes on cash		—				—				(2,474		)		—				(2,474		)
	Net increase (decrease) in cash		8,114				(4,017		)		38,675				—				42,772
	Cash at beginning of period		18,758				(445		)		(3,462		)		—				14,851
	Cash at end of period		$	26,872			$	(4,462	)		$	35,213			$	—			$	57,623
			For the Year Ended December 31, 2011
			Magnum Hunter				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources				Subsidiaries				Subsidiaries								Resources
			Corporation																Corporation
																			Consolidated
	Cash flow from operating activities		$	(203,251	)		$	136,974			$	100,115			$	—			$	33,838
	Cash flow from investing activities		(90,464		)		(136,489		)		(134,762		)		—				(361,715		)
	Cash flow from financing activities		310,917				(310		)		31,586				—				342,193
	Effect of exchange rate changes on cash		—				—				(19		)		—				(19		)
	Net increase (decrease) in cash		17,202				175				(3,080		)		—				14,297
	Cash at beginning of period		1,556				(620		)		(382		)		—				554
	Cash at end of period		$	18,758			$	(445	)		$	(3,462	)		$	—			$	14,851
Debt Securities Under Universal Shelf Registration Statement Form S-4	'
CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	'
Schedule of condensed consolidating balance sheets	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
			As of December 31, 2013
			Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources								Subsidiaries				Subsidiaries								Resources
			Corporation																				Corporation
																							Consolidated
	ASSETS
	Current assets		$	53,161			$	6,013			$	43,841			$	21,083			$	(3,372	)		$	120,726
	Intercompany accounts receivable		965,138				—				—				—				(965,138		)		—
	Property and equipment (using successful efforts accounting)		7,214				—				1,272,027				234,838				—				1,514,079
	Investment in subsidiaries		372,236				—				102,314				—				(474,550		)		—
	Other assets		17,308				—				100,894				103,644				—				221,846
	Total Assets		$	1,415,057			$	6,013			$	1,519,076			$	359,565			$	(1,443,060	)		$	1,856,651
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities		$	54,826			$	2,035			$	97,520			$	32,894			$	(3,410	)		$	183,865
	Intercompany accounts payable		—				45,661				921,237				(1,795		)		(965,103		)		—
	Long-term liabilities		818,651				—				39,067				127,663				—				985,381
	Redeemable preferred stock		100,000				—				—				136,675				—				236,675
	Shareholders' equity (deficit)		441,580				(41,683		)		461,252				64,128				(474,547		)		450,730
	Total Liabilities and Shareholders' Equity		$	1,415,057			$	6,013			$	1,519,076			$	359,565			$	(1,443,060	)		$	1,856,651
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
			As of December 31, 2012
			Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources								Subsidiaries				Subsidiaries								Resources
			Corporation																				Corporation
																							Consolidated
	ASSETS
	Current assets		$	63,167			$	703			$	60,552			$	111,126			$	(31,229	)		$	204,319
	Intercompany accounts receivable		803,834				—				—				—				(803,834		)		—
	Property and equipment (using successful efforts accounting)		9,596				18,257				1,276,467				620,093				—				1,924,413
	Investment in subsidiaries		763,856				—				101,341				102,354				(967,551		)		—
	Other assets		20,849				—				5,451				43,600				—				69,900
	Total Assets		$	1,661,302			$	18,960			$	1,443,811			$	877,173			$	(1,802,614	)		$	2,198,632
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities		$	28,503			$	2,291			$	117,511			$	125,727			$	(30,376	)		$	243,656
	Intercompany accounts payable		—				58,966				508,254				236,636				(803,856		)		—
	Long-term liabilities		831,286				1,274				97,271				112,615				—				1,042,446
	Redeemable preferred stock		100,000				—				—				100,878				—				200,878
	Shareholders' equity (deficit)		701,513				(43,571		)		720,775				301,317				(968,382		)		711,652
	Total Liabilities and Shareholders' Equity		$	1,661,302			$	18,960			$	1,443,811			$	877,173			$	(1,802,614	)		$	2,198,632
Schedule of condensed consolidating statements of operations	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
			For the Year Ended December 31, 2013
			Magnum Hunter				PRC Williston, LLC (1)				100% Owned Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
			Resources								Subsidiaries				Subsidiaries								Resources
			Corporation																				Corporation
																							Consolidated
	Revenues		$	2,629			$	—			$	254,209			$	28,172			$	(4,599	)		$	280,411
	Expenses		112,754				3,583				394,328				54,231				(10,136		)		554,760
	Loss from continuing operations before equity in net income of subsidiaries		(110,125		)		(3,583		)		(140,119		)		(26,059		)		5,537				(274,349		)
	Equity in net income of subsidiaries		(298,775		)		—				(424		)		—				299,199				—
	Loss from continuing operations before income tax		(408,900		)		(3,583		)		(140,543		)		(26,059		)		304,736				(274,349		)
	Income tax benefit		28,989				—				41,305				3				—				70,297
	Loss from continuing operations		(379,911		)		(3,583		)		(99,238		)		(26,056		)		304,736				(204,052		)
	Income from discontinued operations, net of tax		(7,813		)		(1,674		)		13,085				(76,335		)		1,606				(71,131		)
	Gain on disposal of discontinued operations, net of tax		144,378				7,145				(18,507		)		(73,852		)		(7,145		)		52,019
	Net income (loss)		(243,346		)		1,888				(104,660		)		(176,243		)		299,197				(223,164		)
	Net loss attributable to non-controlling interest		—				—				—				—				988				988
	Net loss attributable to Magnum Hunter Resources Corporation		(243,346		)		1,888				(104,660		)		(176,243		)		300,185				(222,176		)
	Dividends on preferred stock		(35,464		)		—				—				(21,241		)		—				(56,705		)
	Net income (loss) attributable to common shareholders		$	(278,810	)		$	1,888			$	(104,660	)		$	(197,484	)		$	300,185			$	(278,881	)
			For the Year Ended December 31, 2012
			Magnum Hunter				PRC Williston, LLC (1)				100% Owned Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
			Resources								Subsidiaries				Subsidiaries								Resources
			Corporation																				Corporation
																							Consolidated
	Revenues		$	729			$	—			$	122,703			$	12,955			$	3,969			$	140,356
	Expenses		54,047				3,289				177,489				9,929				34,570				279,324
	Loss from continuing operations before equity in net income of subsidiaries		(53,318		)		(3,289		)		(54,786		)		3,026				(30,601		)		(138,968		)
	Equity in net income of subsidiaries		(97,191		)		—				458				(23,362		)		120,095				—
	Loss from continuing operations before income tax		(150,509		)		(3,289		)		(54,328		)		(20,336		)		89,494				(138,968		)
	Income tax benefit		5,937				—				13,375								—				19,312
	Loss from continuing operations		(144,572		)		(3,289		)		(40,953		)		(20,336		)		89,494				(119,656		)
	Income from discontinued operations, net of tax		—				(11,602		)		(11,056		)		(8,418		)		11,602				(19,474		)
	Gain on disposal of discontinued operations, net of tax		—				—				2,409				—				—				2,409
	Net income (loss)		(144,572		)		(14,891		)		(49,600		)		(28,754		)		101,096				(136,721		)
	Net income attributable to non-controlling interest		—				—				—				—				4,013				4,013
	Net loss attributable to Magnum Hunter Resources Corporation		(144,572		)		(14,891		)		(49,600		)		(28,754		)		105,109				(132,708		)
	Dividends on preferred stock		(22,842		)		—				—				(11,864		)		—				(34,706		)
	Net income (loss) attributable to common shareholders		$	(167,414	)		$	(14,891	)		$	(49,600	)		$	(40,618	)		$	105,109			$	(167,414	)
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
			For the Year Ended December 31, 2011
			Magnum Hunter				PRC Williston, LLC (1)				100% Owned Guarantor				Non Guarantor				(1) Eliminations				Magnum Hunter
			Resources								Subsidiaries				Subsidiaries								Resources
			Corporation																				Corporation
																							Consolidated
	Revenues		$	1,071			$	—			$	54,545			$	5,903			$	4,936			$	66,455
	Expenses		68,772				4,715				48,788				7,677				(3,821		)		126,131
	Loss from continuing operations before equity in net income of subsidiaries		(67,701		)		(4,715		)		5,757				(1,774		)		8,757				(59,676		)
	Equity in net income of subsidiaries		(6,906		)		—				(2,196		)		(939		)		10,041				—
	Loss from continuing operations before income tax		(74,607		)		(4,715		)		3,561				(2,713		)		18,798				(59,676		)
	Income tax benefit		—				—				3,733				(357		)		(514		)		2,862
	Loss from continuing operations		(74,607		)		(4,715		)		7,294				(3,070		)		18,284				(56,814		)
	Income from discontinued operations, net of tax		—				1,698				(30,364		)		12,306				(3,238		)		(19,598		)
	Gain on disposal of discontinued operations, net of tax		—				—				—				—				—				—
	Net income (loss)		(74,607		)		(3,017		)		(23,070		)		9,236				15,046				(76,412		)
	Net income attributable to non-controlling interest		—				—				—				—				(249		)		(249		)
	Net loss attributable to Magnum Hunter Resources Corporation		(74,607		)		(3,017		)		(23,070		)		9,236				14,797				(76,661		)
	Dividends on preferred stock		(14,007		)		—				—				—				—				(14,007		)
	Net income (loss) attributable to common shareholders		$	(88,614	)		$	(3,017	)		$	(23,070	)		$	9,236			$	14,797			$	(90,668	)
Schedule of condensed consolidating statements of comprehensive income (loss)	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Comprehensive Income (Loss)
	(in thousands)
		For the Year Ended December 31, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
	Net income (loss)	$	(243,346	)		$	1,888			$	(104,660	)		$	(176,243	)		$	299,197			$	(223,164	)
	Foreign currency translation loss	—				—				—				(10,928		)		—				(10,928		)
	Unrealized gain (loss) on available for sale securities	8,262				—				(84		)		—				—				8,178
	Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	(8,262		)		—				—				—				—				(8,262		)
	Comprehensive income (loss)	(243,346		)		1,888				(104,744		)		(187,171		)		299,197				(234,176		)
	Comprehensive (income) loss attributable to non-controlling interest	—				—				—				—				988				988
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(243,346	)		$	1,888			$	(104,744	)		$	(187,171	)		$	300,185			$	(233,188	)
		For the Year Ended December 31, 2012
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
	Net income (loss)	$	(144,572	)		$	(14,891	)		$	(49,600	)		$	(28,754	)		$	101,096			$	(136,721	)
	Foreign currency translation loss	—				—				—				3,883				—				3,883
	Unrealized gain (loss) on available for sale securities	—				—				(309		)		—				—				(309		)
	Comprehensive income (loss)	(144,572		)		(14,891		)		(49,909		)		(24,871		)		101,096				(133,147		)
	Comprehensive (income) loss attributable to non-controlling interest	—				—				—				—				4,013				4,013
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(144,572	)		$	(14,891	)		$	(49,909	)		$	(24,871	)		$	105,109			$	(129,134	)
		For the Year Ended December 31, 2011
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
		Resources								Subsidiaries				Subsidiaries								Resources
		Corporation																				Corporation
																						Consolidated
	Net income (loss)	$	(74,607	)		$	(3,017	)		$	(23,070	)		$	9,236			$	15,046			$	(76,412	)
	Foreign currency translation loss	—				—				—				(12,477		)		—				(12,477		)
	Unrealized gain (loss) on available for sale securities	—				—				14				—				—				14
	Comprehensive income (loss)	(74,607		)		(3,017		)		(23,056		)		(3,241		)		15,046				(88,875		)
	Comprehensive (income) loss attributable to non-controlling interest	—				—				—				—				(249		)		(249		)
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(74,607	)		$	(3,017	)		$	(23,056	)		$	(3,241	)		$	14,797			$	(89,124	)
Schedule of condensed consolidating statements of cash flows	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Cash Flows
	(in thousands)
			For the Year Ended December 31, 2013
			Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources								Subsidiaries				Subsidiaries								Resources
			Corporation																				Corporation
																							Consolidated
	Cash flow from operating activities		$	(371,351	)		$	(1,932	)		$	397,213			$	101,085			$	(13,304	)		$	111,711
	Cash flow from investing activities		422,303				15,236				(411,473		)		(153,926		)		—				(127,860		)
	Cash flow from financing activities		(29,929		)		(13,304		)		796				29,789				13,304				656
	Effect of exchange rate changes on cash		—				—				—				(417		)		—				(417		)
	Net increase (decrease) in cash		21,023				—				(13,464		)		(23,469		)		—				(15,910		)
	Cash at beginning of period		26,872				—				(4,187		)		34,938				—				57,623
	Cash at end of period		$	47,895			$	—			$	(17,651	)		$	11,469			$	—			$	41,713
			For the Year Ended December 31, 2012
			Magnum Hunter				PRC Williston, LLC				Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources								Subsidiaries				Subsidiaries								Resources
			Corporation																				Corporation
																							Consolidated
	Cash flow from operating activities		$	(458,921	)		$	1,256			$	281,782			$	235,104			$	(1,210	)		$	58,011
	Cash flow from investing activities		(364,045		)		(49		)		(287,204		)		(357,912		)		3				(1,009,207		)
	Cash flow from financing activities		831,080				(1,207		)		1,781				163,581				1,207				996,442
	Effect of exchange rate changes on cash		—				—				—				(2,474		)		—				(2,474		)
	Net increase (decrease) in cash		8,114				—				(3,641		)		38,299				—				42,772
	Cash at beginning of period		18,758				—				(546		)		(3,361		)		—				14,851
	Cash at end of period		$	26,872			$	—			$	(4,187	)		$	34,938			$	—			$	57,623
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Cash Flows
	(in thousands)
			For the Year Ended December 31, 2011
			Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor				Non Guarantor				Eliminations				Magnum Hunter
			Resources								Subsidiaries				Subsidiaries								Resources
			Corporation																				Corporation
																							Consolidated
	Cash flow from operating activities		$	(203,251	)		$	(1,738	)		$	138,855			$	98,048			$	1,924			$	33,838
	Cash flow from investing activities		(90,464		)		(175		)		(141,954		)		(129,111		)		(11		)		(361,715		)
	Cash flow from financing activities		310,917				1,913				3,206				28,070				(1,913		)		342,193
	Effect of exchange rate changes on cash		—				—				—				(19		)		—				(19		)
	Net increase (decrease) in cash		17,202				—				107				(3,012		)		—				14,297
	Cash at beginning of period		1,556				—				(653		)		(349		)		—				554
	Cash at end of period		$	18,758			$	—			$	(546	)		$	(3,361	)		$	—			$	14,851

SUBSEQUENT_EVENTS_Tables

SUBSEQUENT EVENTS (Tables)	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Summary of commodity derivatives	'
	The table below is a summary of our commodity derivatives entered into subsequent to December 31, 2013 through the date of this report:
				Weighted Avg
	Natural Gas	Period	MMBTU/day	Price per MMBTU
	Swaps	Jan 2014 - Dec 2014	21,000	$4.27
		Jan 2015 - Dec 2015	20,000	$4.18
	Ceilings purchased (call)	Jan 2014 - Dec 2014	6,000	$5.50

ORGANIZATION_NATURE_OF_OPERATI3

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Summary of Significant Accounting Policies	'		'	'
Restricted cash	$5,000,000		$1,500,000	'
Inventory	'		'	'
Materials and supplies	6,790,000		11,531,000	'
Commodities	368,000		1,095,000	'
Materials included in other long term assets	0		-3,464,000	'
Inventory	7,158,000		9,162,000	'
Mineral interests in properties:	'		'	'
Depreciation, depletion, amortization and accretion	99,198,000		59,730,000	23,246,000
Foreign currency translation gain (loss)	-10,928,000		3,883,000	-12,477,000
Fair Value Inputs, Discount Rate	13.00%		'	'
Leasehold impairments	'		0	0
Oil and natural gas properties	'		'	'
Mineral interests in properties:	'		'	'
Unproved leasehold costs	469,337,000		645,164,000	'
Proved leasehold costs	336,357,000		454,556,000	'
Wells and related equipment and facilities	438,275,000		727,711,000	'
Uncompleted wells, equipment and facilities	97,748,000		71,665,000	'
Advances to operators for wells in progress	13,571,000		9,563,000	'
Depreciation, depletion, amortization and accretion	69,000,000		49,200,000	18,400,000
Time period for capitalization of significant construction projects (more than six months)	'6 months		'	'
Interest cost capitalized during period	2,600,000		4,400,000	'
Prc Wiliston Llc [Member]	'		'	'
Summary of Significant Accounting Policies	'		'	'
Consolidated controlling interest (as a percent)	87.50%		'	'
Eureka Hunter Holdings, LLC	'		'	'
Summary of Significant Accounting Policies	'		'	'
Consolidated controlling interest (as a percent)	56.40%		61.00%	'
Eureka Hunter Pipeline LLC [Member]	'		'	'
Summary of Significant Accounting Policies	'		'	'
Consolidated entities ownership percentage in entity (as a percent)	100.00%		'	'
Penn Virginia [Member]	'		'	'
Summary of Significant Accounting Policies	'		'	'
Available-for-sale Securities, sale of securities	50,562,000	[1]	'	'
Williston Basin [Member]	'		'	'
Mineral interests in properties:	'		'	'
Leasehold impairments	89,167,000		59,214,000	0
Frac Sand [Member]	'		'	'
Inventory	'		'	'
Materials included in other long term assets	'		$3,500,000	'
[1]	Available for sale securities above includes $147,000 that has been classified as held for sale associated with the classification of the MHP subsidiary.

ORGANIZATION_NATURE_OF_OPERATI4

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Gas and Oil Acreage	'	'	'
Results of Operations, Impairment of Oil and Gas Properties	$9,968,000	$3,772,000	$0
Oil and natural gas sales	197,599,000	114,659,000	58,726,000
Required Period To Remit Liabilities Under Revenue Payable	'30 days	'	'
Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves Future Unweighted Arithmetic Average Period To Estimate Commodity Price	'12 months	'	'
Due Period of Joint Interest Owner Obligations	'30 days	'	'
Depreciation, depletion, amortization and accretion	99,198,000	59,730,000	23,246,000
Accounts payable	107,860,000	196,515,000	'
Exploration and Abandonment Costs	'	'	'
Geological and geophysical	1,402,000	2,570,000	1,497,000
Leasehold impairments	'	0	0
Exploration Abandonment and Impairment Expense	97,342,000	78,221,000	2,605,000
Allowance for Doubtful Accounts Receivable	300,000	400,000	'
Minimum	'	'	'
Exploration and Abandonment Costs	'	'	'
Accounts Receivable Oil and Gas Period After Production Outstanding Balance Due	'30 days	'	'
Maximum	'	'	'
Exploration and Abandonment Costs	'	'	'
Accounts Receivable Oil and Gas Period After Production Outstanding Balance Due	'60	'	'
Appalachian [Member]	'	'	'
Exploration and Abandonment Costs	'	'	'
Leasehold impairments	6,773,000	15,033,000	802,000
Williston Basin [Member]	'	'	'
Gas and Oil Acreage	'	'	'
Results of Operations, Impairment of Oil and Gas Properties	8,498,000	3,631,000	0
Exploration and Abandonment Costs	'	'	'
Leasehold impairments	89,167,000	59,214,000	0
Appalachian Region [Member]	'	'	'
Gas and Oil Acreage	'	'	'
Results of Operations, Impairment of Oil and Gas Properties	1,151,000	76,000	0
South Texas [Member]	'	'	'
Gas and Oil Acreage	'	'	'
Results of Operations, Impairment of Oil and Gas Properties	319,000	65,000	0
Exploration and Abandonment Costs	'	'	'
Leasehold impairments	0	1,404,000	306,000
Oil and natural gas properties	'	'	'
Gas and Oil Acreage	'	'	'
Time period for capitalization of significant construction projects (more than six months)	'6 months	'	'
Interest cost capitalized during period	2,600,000	4,400,000	'
Depreciation, depletion, amortization and accretion	69,000,000	49,200,000	18,400,000
Oil [Member]	'	'	'
Gas and Oil Acreage	'	'	'
Oil and natural gas sales	140,426,000	77,172,000	37,520,000
Natural Gas	'	'	'
Gas and Oil Acreage	'	'	'
Oil and natural gas sales	41,867,000	36,657,000	21,206,000
NGL [Member]	'	'	'
Gas and Oil Acreage	'	'	'
Oil and natural gas sales	$15,306,000	$830,000	$0

ORGANIZATION_NATURE_OF_OPERATI5

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 3) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Capitalized costs of oil and gas properties	'	'	'
Depreciation	$15,600,000	$8,100,000	$7,800,000
Operating leases, term	'3 years	'	'
Future minimum base rentals of Transtex Hunter's non-cancelable leases	'	'	'
2014	504,000	'	'
2015	457,000	'	'
2016	239,000	'	'
Payment of deferred financing costs	1,246,000	20,313,000	11,577,000
Amortization and write-off of deferred financing costs	4,818,000	7,400,000	'
Amortization of deferred financing costs	'	7,100,000	3,600,000
Trans Tex Gas Services	'	'	'
Future minimum base rentals of Transtex Hunter's non-cancelable leases	'	'	'
2014	4,400,000	'	'
2015	900,000	'	'
2016	200,000	'	'
Oil and natural gas properties	'	'	'
Capitalized costs of oil and gas properties	'	'	'
Time period for capitalization of significant construction projects (more than six months)	'6 months	'	'
Interest cost capitalized during period	2,600,000	4,400,000	'
Gas transportation, gathering and processing equipment and other	1,355,288,000	1,908,659,000	'
Less accumulated depreciation and depletion	130,629,000	186,156,000	'
Net capitalized costs	1,224,659,000	1,722,503,000	'
Gas Transportation Gathering Processing and Other Equipment [Member]	'	'	'
Capitalized costs of oil and gas properties	'	'	'
PP&E, Useful Life	'15 years	'	'
Gas transportation, gathering and processing equipment and other	315,642,000	218,656,000	'
Less accumulated depreciation and depletion	26,222,000	16,746,000	'
Net capitalized costs	$289,420,000	$201,910,000	'
Field servicing assets | Minimum	'	'	'
Capitalized costs of oil and gas properties	'	'	'
PP&E, Useful Life	'3 years	'	'
Field servicing assets | Maximum	'	'	'
Capitalized costs of oil and gas properties	'	'	'
PP&E, Useful Life	'10 years	'	'
Furniture and Fixtures Equipment [Member] | Minimum	'	'	'
Capitalized costs of oil and gas properties	'	'	'
PP&E, Useful Life	'5 years	'	'
Furniture and Fixtures Equipment [Member] | Maximum	'	'	'
Capitalized costs of oil and gas properties	'	'	'
PP&E, Useful Life	'15 years	'	'

ORGANIZATION_NATURE_OF_OPERATI6

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 4) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 02, 2012

Apr. 02, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 17, 2012

Feb. 17, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 17, 2012

Feb. 17, 2012

Dec. 31, 2013

Dec. 31, 2012

Apr. 24, 2013

Dec. 31, 2013

Dec. 31, 2013

Trans Tex Gas Services

Trans Tex Gas Services

MHP Subsidiary

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Eagle Ford Hunter

Penn Virginia [Member]

Equity Method Investments [Member]

Customer relationships

Series C Preferred Stock

Green Hunter Energy, Inc.

Green Hunter Energy, Inc.

Green Hunter Energy, Inc.

Green Hunter Energy, Inc.

Green Hunter Energy, Inc.

Green Hunter Energy, Inc.

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Investments [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consideration received, number of shares of common stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,846,722

'

'

'

'

'

'

'

10,000,000

'

'

Consideration received, value of common stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,600,000

'

$600,000

$1,300,000

'

'

'

'

$42,300,000

'

'

Consideration received, number of shares of preferred stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

88,000

'

'

88,000

'

'

'

'

'

'

Consideration received, cumulative preferred dividend rate on preferred stock received (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

Consideration received, value of preferred stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,200,000

1,900,000

'

'

'

'

1,700,000

1,700,000

'

'

'

Available for Sale Securities Activity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available for Sale Securities, fair value at beginning of period

1,958,000

[1]

'

'

'

'

'

'

'

1,958,000

[1]

497,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available for Sale Securities, cost basis from acquisition

'

'

'

'

'

'

'

'

'

0

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available-for-sale Securities, securities received as consideration

'

'

'

'

'

'

'

'

42,300,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available-for-sale Securities, sale of securities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-50,562,000

[1]

'

Available-for-sale Securities, change in fair value recognized in other comprehensive loss

'

'

'

'

'

'

'

'

-84,000

[1]

-309,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available for Sale Securities, fair value at end of period

'

1,958,000

[1]

'

'

497,000

[1]

'

'

'

1,819,000

[1]

1,958,000

[1]

497,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments Activity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments, fair value at beginning of period

2,072,000

[2]

'

'

'

'

'

'

'

2,072,000

[2]

0

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments, Acquired During Period

'

'

'

'

'

'

'

'

'

3,943,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments, decrease in carrying amount return of capital

'

'

'

'

'

'

'

'

-138,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity in net loss recognized in other income (expense)

'

'

'

'

'

'

'

'

-767,000

[2]

-1,333,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Impairment in carrying value of equity method investment recognized in other income (expense)

'

'

'

'

'

'

'

'

-227,000

[2]

-538,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments, fair value at end of period

'

2,072,000

[2]

'

'

0

[2]

'

'

'

940,000

[2]

2,072,000

[2]

0

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost Method Investments Activity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost Method Investments, fair value at beginning of period

0

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost-method Investments, additional cost basis from acquisition

'

'

'

'

'

'

'

'

'

1,870,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost-method Investments, transfers

'

'

'

'

'

'

'

'

'

-1,770,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost-method Investments, decrease in carrying amount return of capital

'

'

'

'

'

'

'

'

'

-100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost Method Investments, fair value at end of period

'

0

'

'

0

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available-for-sale securities, classified as held-for-sale

'

'

'

'

'

'

'

'

'

'

'

'

'

147,000

'

'

'

'

'

'

'

'

'

'

'

'

Long-term other assets

'

6,455,000

'

'

'

'

'

'

1,994,000

6,455,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

350,000

Intangible Assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Discount rate (as a percent)

'

'

'

'

'

'

'

'

13.00%

'

'

13.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset Retirement Obligation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability for current asset retirement obligations

'

2,358,000

'

'

'

'

'

'

53,000

2,358,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset retirement obligation

'

28,322,000

'

'

'

'

'

'

16,163,000

28,322,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Taxes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Uncertain tax positions

'

0

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available-for-sale Securities, Transfers To

'

'

'

'

'

'

'

'

'

1,770,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available-for-sale Securities, Other Adjustments

'

'

'

'

'

'

'

'

-55,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain on disposal of discontinued operations, net of tax

$0

[3]

($35,979,000)

[3]

($84,454,000)

[3]

$172,452,000

[3]

$185,000

$0

($2,101,000)

$4,325,000

$52,019,000

[3],[4],[5]

$2,409,000

[4],[5]

$0

[4],[5]

'

'

'

$2,409,000

'

'

'

'

'

'

'

'

'

$8,262,000

[1]

'

Acquired Finite-lived Intangible Assets, Weighted Average Useful Life

'

'

'

'

'

'

'

'

'

'

'

'8 years 6 months 15 days

'12 years 6 months

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Available for sale securities above includes $147,000 that has been classified as held for sale associated with the classification of the MHP subsidiary.

[2]

Equity method investments includes $350,000 classified as long term other assets.

[3]

The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".

[4]

Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.

[5]

The Companybs effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.

ORGANIZATION_NATURE_OF_OPERATI7

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 5) (Dilutive)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Summarize the outstanding potentially dilutive securities	'	'	'
Potentially dilutive securities outstanding	45,034	39,120	26,130
Series E Preferred Stock	'	'	'
Summarize the outstanding potentially dilutive securities	'	'	'
Potentially dilutive securities outstanding	10,946	10,897	0
Warrants	'	'	'
Summarize the outstanding potentially dilutive securities	'	'	'
Potentially dilutive securities outstanding	17,169	13,376	13,526
Restricted shares granted, not yet issued	'	'	'
Summarize the outstanding potentially dilutive securities	'	'	'
Potentially dilutive securities outstanding	28	0	38
Common stock options	'	'	'
Summarize the outstanding potentially dilutive securities	'	'	'
Potentially dilutive securities outstanding	16,891	14,847	12,566

ORGANIZATION_NATURE_OF_OPERATI8

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 6) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Energy Hunter Securities Inc. [Member]	'	'	'
Summary of Significant Accounting Policies	'	'	'
Minimum Net Capital Required for Broker-Dealer Subsidiary	$5,000	'	'
Ratio of Indebtedness to Net Capital	0.0667	'	'
Net Capital	77,953	71,928	'
Aggregate Indebtedness	16,657	291,307	'
Sentra Corporation [Member]	'	'	'
Summary of Significant Accounting Policies	'	'	'
Regulated Operating Revenue, Gas	$216,000	$511,000	$61,000

ORGANIZATION_NATURE_OF_OPERATI9

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Assets Held for Sale) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]	'	'
Current portion	$5,366,000	$500,000
Long term portion	162,687,000	0
Magnum Hunter Production, Inc. [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Current portion	3,495,000	0
Long term portion	99,616,000	0
Total assets held for sale	103,111,000	0
Wilson Hunter Canada, Inc. [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Current portion	1,871,000	0
Long term portion	63,071,000	0
Total assets held for sale	64,942,000	0
Alpha Hunter Drilling Llc [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Current portion	0	500,000
Long term portion	0	0
Total assets held for sale	$0	$500,000

Recovered_Sheet1

ORGANIZATION, NATURE OF OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details 7) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accounting Policies [Abstract]	'	'	'
Foreign currency translation gain (loss)	($10,928)	$3,883	($12,477)

DIVESTITURES_AND_DISCONTINUED_2

DIVESTITURES AND DISCONTINUED OPERATIONS (Details) (USD $)

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

Feb. 17, 2012

Sep. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Feb. 17, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 17, 2012

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Sep. 26, 2013

Sep. 30, 2013

Dec. 30, 2013

Apr. 24, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Feb. 03, 2014

Feb. 03, 2014

Series C Preferred Stock

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

WHI Canada Capital Loss Utilization Against Capital Gains [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Wilson Hunter Canada, Inc. [Member]

Williston Hunter Inc [Member]

Williston Hunter Inc [Member]

Enduro Operating LLC [Member]

Penn Virginia [Member]

Penn Virginia [Member]

Penn Virginia [Member]

Minimum

Maximum

Subsequent event

Subsequent event

Series C Preferred Stock

Well

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Penn Virginia [Member]

Penn Virginia [Member]

Hunter Disposal LLC [Member]

Penn Virginia [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Hunter Disposal LLC [Member]

Discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity ownership interest sold (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total consideration received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$9,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$422,100,000

'

'

'

'

'

'

Cash consideration received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,200,000

'

'

'

'

'

'

'

'

'

'

'

32,500,000

'

44,100,000

379,800,000

'

50,600,000

'

'

'

'

Consideration received, number of shares of common stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,846,722

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

Consideration received, value of common stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

42,300,000

'

'

'

'

'

'

Common stock issued (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.79

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$4.23

'

'

'

'

'

'

Sales proceeds used to pay down outstanding borrowings

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

325,000,000

'

'

'

'

'

'

Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities

'

'

'

'

'

'

'

'

'

'

-8,262,000

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,300,000

'

'

'

'

'

Final adjustment calculation amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

26,600,000

56,400,000

Payable to Penn Virginia

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22,000,000

33,000,000

'

'

Impairment expense related to discontinued operations, net of tax

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

56,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Impairment expense related to discontinued operations

'

72,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,600,000

64,800,000

78,500,000

324,000

0

'

'

'

'

'

'

'

'

'

'

'

Consideration received, number of shares of preferred stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

88,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cumulative dividend rate for cumulative preferred stock of GreenHunter Energy, Inc. (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

10.25%

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of preferred stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,200,000

'

'

'

1,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of promissory notes convertible into GreenHunter Energy, Inc common stock (in shares)

880,000

'

'

'

'

'

'

'

'

'

'

'

'

'

880,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of promissory notes convertible into GreenHunter Energy, Inc common stock, conversion price (in dollars per share)

$2.50

'

'

'

'

'

'

'

'

'

'

'

'

'

$2.50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of embedded derivative asset

'

'

'

'

'

'

'

'

'

'

'

'

'

'

405,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjusted cash proceeds for changes in working capital to reflect the effective date of the sale

'

'

'

'

'

'

'

'

'

'

'

783,000

'

'

'

'

'

783,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain on sale of discontinued operations, before tax

'

'

'

'

'

'

'

'

'

'

53,389,000

3,706,000

0

'

'

'

3,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain on sale of discontinued operations, tax

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-1,400,000

1,300,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Results reclassified to discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

'

'

'

'

'

'

'

'

'

91,364,000

133,643,000

60,633,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expenses

'

'

'

'

'

'

'

'

'

'

-174,049,000

[1]

-160,127,000

[1]

-79,431,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other income (expense)

'

'

'

'

'

'

'

'

'

'

6,847,000

3,431,000

1,366,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss from discontinued operations

'

'

'

'

'

'

'

'

'

'

-75,838,000

-23,053,000

-17,432,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Discontinued Operation, Tax Effect of Income (Loss) from Discontinued Operation During Phase-out Period

'

'

'

'

'

'

'

'

'

'

-4,707,000

[2]

-3,579,000

[2]

2,166,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax

'

'

'

'

'

'

'

'

'

'

-71,131,000

-19,474,000

-19,598,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income tax benefit (expense)

'

'

'

'

'

'

'

'

'

'

3,336,000

2,283,000

-2,166,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income (loss) from discontinued operations, net of tax

'

'

16,845,000

[3]

324,000

[3]

-80,554,000

[3]

-7,746,000

[3]

-22,306,000

-1,102,000

-1,789,000

5,723,000

-71,131,000

[3]

-19,474,000

-19,598,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain on disposal of discontinued operations, net of taxes

'

'

0

[4]

-35,979,000

[4]

-84,454,000

[4]

172,452,000

[4]

185,000

0

-2,101,000

4,325,000

52,019,000

[4],[5],[6]

2,409,000

[5],[6]

0

[5],[6]

'

'

'

2,409,000

'

'

'

'

'

92,400,000

'

'

'

'

-38,100,000

'

'

172,500,000

'

'

'

'

'

Effective tax rate on the loss from discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.60%

'

'

'

'

'

6.20%

'

'

'

'

'

'

'

'

'

'

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

'

'

-19,112,000

-17,065,000

-19,598,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exploration expense relating to discontinued operations of MHP and WHI Canada

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

19,600,000

38,700,000

0

'

'

'

'

'

'

'

'

'

'

'

Sale of operated working interest in number of wells

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

180

'

'

'

'

'

'

'

Preliminary loss recognized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$8,200,000

'

'

'

'

'

'

'

Period after closing for the customary adjustments to the purchase price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'120 days

'

'

'

'

'

'

'

[1]

Includes impairment expense of $78.5 million, $324,000, and none for the years ended December 31, 2013, 2012, and 2011, respectively, and exploration expense of $19.6 million, $38.7 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively relating to the discontinued operations of MHP and WHI Canada, which is recorded in income (loss) from discontinued operations.

[2]

The Companybs effective tax rate on the loss from discontinued operations is 6.2% primarily due to the significant losses generated in WHI Canada, which has an overall lower statutory tax rate further lowered by the utilization of certain net operating losses.

[3]

The quarter-ended September 30, 2013, loss from discontinued operations was primarily driven by impairment expense of $72.5 million, as management determined a significant portion of the non-core acreage would not be utilized.

[4]

The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".

[5]

Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.

[6]

The Companybs effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.

FAIR_VALUE_OF_FINANCIAL_INSTRU2

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

In Thousands, except Per Share data, unless otherwise specified

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Commodity derivative

Commodity derivative

Commodity derivative

Commodity derivative

Commodity derivative

Commodity derivative

Convertible security derivative assets

Convertible security derivative assets

Convertible security derivative assets

Convertible security derivative assets

Convertible security derivative assets

Preferred Stock Embedded Derivative

Preferred Stock Embedded Derivative

Preferred Stock Embedded Derivative

Preferred Stock Embedded Derivative

Preferred Stock Embedded Derivative

Preferred Stock Embedded Derivative

Preferred Stock Embedded Derivative

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Level 3

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Level 3

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Recurring [Member]

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Level 1

Level 1

Level 2

Level 2

Level 1

Level 1

Level 2

Level 2

Level 3

Level 3

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated volatility (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

'

'

'

'

25.00%

'

'

'

'

'

'

Credit spread rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13.90%

'

'

'

'

'

'

Total consideration paid for acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$568,000

'

'

'

'

'

'

Assumptions and methodology used for calculating fair value of assets and liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Life (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'3 years 1 month 6 days

'

'

'

'

'

'

'

'

'

'

'

Risk-free interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

0.93%

'

'

'

'

'

'

'

'

'

'

'

Dividend

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

'

'

'

'

'

'

'

Common stock issued (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

$1.18

'

'

'

'

'

'

'

'

'

'

'

Fair Value Measurements on a Recurring Basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available for sale securities

1,819

1,958

0

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative assets

'

'

'

'

'

'

0

0

554

4,882

0

0

'

0

0

0

0

'

'

'

'

'

'

'

Total assets at fair value

1,819

1,958

554

4,882

79

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative liabilities

'

'

'

'

'

'

0

0

2,279

7,477

0

0

'

'

'

'

'

'

0

0

0

0

75,934

43,548

Total liabilities at fair value

$0

$0

$2,279

$7,477

$75,934

$43,548

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

FAIR_VALUE_OF_FINANCIAL_INSTRU3

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 2) (Preferred Stock Embedded Derivative, Level 3, Embedded Derivatives, Liabilities, USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Preferred Stock Embedded Derivative | Level 3 | Embedded Derivatives, Liabilities	'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'
Fair value beginning balance	($43,548)
Issued embedded derivative liability	-14,645
Change in fair value recognized in other income (expense)	-17,741
Fair value ending balance	($75,934)

FAIR_VALUE_OF_FINANCIAL_INSTRU4

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 3) (Convertible security derivative assets, Level 3, Embedded Derivatives, Assets, USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Convertible security derivative assets | Level 3 | Embedded Derivatives, Assets	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'
Fair value beginning balance	$264
Issued embedded derivative asset	0
Change in fair value recognized in other income (expense)	-185
Fair value ending balance	$79

FAIR_VALUE_OF_FINANCIAL_INSTRU5

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 4) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Estimated Fair Value | Level 2 | Senior Notes	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of long-term debt	$651,300	[1]	$613,500	[1]
Estimated Fair Value | Level 3 | Senior Revolving Credit Facility	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of long-term debt	218,000	[2]	225,000	[2]
Estimated Fair Value | Level 3 | Eureka Hunter Pipeline, LLC second lien term loan	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of long-term debt	58,921	[3]	58,550	[3]
Estimated Fair Value | Level 3 | Equipment note payable	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of long-term debt	17,676	[3]	17,450	[3]
Carrying Amount | Level 2 | Senior Notes	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of long-term debt	597,230	[1]	597,212	[1]
Carrying Amount | Level 3 | Senior Revolving Credit Facility	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of long-term debt	218,000	[2]	225,000	[2]
Carrying Amount | Level 3 | Eureka Hunter Pipeline, LLC second lien term loan	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of long-term debt	50,000	[3]	50,000	[3]
Carrying Amount | Level 3 | Equipment note payable	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of long-term debt	$18,615	[3]	$18,548	[3]
[1]	The fair value of the Company's Senior Notes is based on quoted market prices.
[2]	The carrying value of each of the MHR Senior Revolving Credit Facility and Magnum Hunter's second lien term loan approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us at such date.
[3]	The fair value of (a) Eureka Hunter Pipelinebs second lien term loan and (b) equipment note payable, is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.

FAIR_VALUE_OF_FINANCIAL_INSTRU6

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 5) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'
Acquisitions	'		$532,200		'
Impairment of oil and gas properties	9,968		3,772		0
Nonrecurring | Level 1	'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'
Proved properties impaired	0	[1]	0	[1]	'
Acquisitions	0	[2]	'		'
Total proved oil and gas properties, fair value	0		0		'
Nonrecurring | Level 2	'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'
Proved properties impaired	0	[1]	0	[1]	'
Acquisitions	0	[2]	'		'
Total proved oil and gas properties, fair value	0		0		'
Nonrecurring | Level 3	'		'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'		'
Proved properties impaired	58,082	[1]	1,024	[1]	'
Acquisitions	532,150	[2]	'		'
Total proved oil and gas properties, fair value	$590,232		$1,024		'
[1]	The Company recorded impairment charges from continuing operations of $10.0 million and $3.8 million during the years ended December 31, 2013 and 2012, respectively, as a result of writing down the carrying value of certain properties to fair value. In order to determine fair value, Magnum Hunter compares net capitalized costs of proved oil and natural gas properties to estimated undiscounted future net cash flows using management's expectations of economically recoverable reserves. If the net capitalized cost exceeds the undiscounted future net cash flows, Magnum Hunter impairs the net cost basis down to the discounted future net cash flows, which is management's estimate of fair value. Significant inputs used to determine the fair value include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. The underlying commodity prices embedded in the Company's estimated cash flows are the product of a process that begins with third party analyst forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Magnum Hunter's management believes will impact realizable prices. The inputs used by management for the fair value measurements utilized in this review include significant unobservable inputs, and therefore, the fair value measurements employed are classified as Level 3 for these types of assets.
[2]	Magnum Hunter records the fair value of assets and liabilities acquired in business combinations. During the year ended DecemberB 31, 2012, Magnum Hunter acquired oil and natural gas properties with a fair value of $532.2 million. Properties acquired are recorded at fair value, which correlates to the discounted future net cash flow. Significant inputs used to determine the fair value of proved properties include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. The underlying commodity prices embedded in the Company's estimated cash flows are the product of a process that begins with third party analyst forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Magnum Hunter's management believes will impact realizable prices. For acquired unproved properties, the market-based weighted average cost of capital rate is subjected to additional project specific risking factors. The inputs used by management for the fair value measurements of these acquired oil and natural gas properties include significant unobservable inputs, and therefore, the fair value measurements employed are classified as Level 3 for these types of assets.

FINANCIAL_INSTRUMENTS_AND_DERI2

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details)	Dec. 31, 2013
	MMBTU
Natural Gas | Swaps | Jan 2014 - Dec 2014	'
Derivative Instruments	'
Natural gas commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	4.13
Natural Gas | Ceilings purchased (call) | Jan 2014 - Dec 2014	'
Derivative Instruments	'
Natural gas commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	6.15
Natural Gas | Ceilings sold (call) | Jan 2014 - Dec 2014	'
Derivative Instruments	'
Natural gas commodity derivatives contract units per day (MMBTU)	26,000
Price per unit	5.47
Natural Gas | Floors purchased (put) | Jan 2014 - Dec 2014	'
Derivative Instruments	'
Natural gas commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	4.25
Natural Gas | Floors sold (put) | Jan 2014 - Dec 2014	'
Derivative Instruments	'
Natural gas commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	3.75
Crude Oil | Collars | Jan 2014 - Dec 2014	'
Derivative Instruments	'
Crude oil commodity derivatives contract units per day (Bbl)	663	[1]
Crude Oil | Collars | Jan 2014 - Dec 2014 | Minimum	'
Derivative Instruments	'
Price per unit	85	[1]
Crude Oil | Collars | Jan 2014 - Dec 2014 | Maximum	'
Derivative Instruments	'
Price per unit	91.25	[1]
Crude Oil | Collars | Jan 2015 - Dec 2015	'
Derivative Instruments	'
Crude oil commodity derivatives contract units per day (Bbl)	259	[1]
Crude Oil | Collars | Jan 2015 - Dec 2015 | Minimum	'
Derivative Instruments	'
Price per unit	85	[1]
Crude Oil | Collars | Jan 2015 - Dec 2015 | Maximum	'
Derivative Instruments	'
Price per unit	91.25	[1]
Crude Oil | Ceilings sold (call) | Jan 2015 - Dec 2015	'
Derivative Instruments	'
Crude oil commodity derivatives contract units per day (Bbl)	1,570
Price per unit	120
Crude Oil | Floors sold (put) | Jan 2014 - Dec 2014	'
Derivative Instruments	'
Crude oil commodity derivatives contract units per day (Bbl)	663
Price per unit	65
Crude Oil | Floors sold (put) | Jan 2015 - Dec 2015	'
Derivative Instruments	'
Crude oil commodity derivatives contract units per day (Bbl)	259
Price per unit	70
Crude Oil | Traditional three-way collars | Jan 2014 - Dec 2014	'
Derivative Instruments	'
Crude oil commodity derivatives contract units per day (Bbl)	4,000	[2]
Price per unit	85	[2]
Crude Oil | Traditional three-way collars | Jan 2014 - Dec 2014 | Minimum	'
Derivative Instruments	'
Price per unit	64.94	[2]
Crude Oil | Traditional three-way collars | Jan 2014 - Dec 2014 | Maximum	'
Derivative Instruments	'
Price per unit	102.5	[2]
[1]	A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.
[2]	These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.

FINANCIAL_INSTRUMENTS_AND_DERI3

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value	'	'
Gross Derivative Assets	$633	$5,146
Gross Derivative Liabilities	-78,213	-51,025
Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	554	4,882
Gross Derivative Liabilities	-2,279	-7,477
Financial	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	79	264
Gross Derivative Liabilities	-75,934	-43,548
Derivative assets - current | Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	529	4,882
Derivative assets - current | Financial	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	79	264
Derivatives and other long term assets | Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	25	0
Derivative and other current liabilities | Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Liabilities	-1,903	-3,501
Derivative liabilities - long term | Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Liabilities	-376	-3,976
Derivative liabilities - long term | Financial	'	'
Derivatives, Fair Value	'	'
Gross Derivative Liabilities	($75,934)	($43,548)

FINANCIAL_INSTRUMENTS_AND_DERI4

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'
Realized gain (loss)	($8,216)	$11,294	($2,136)
Unrealized gain (loss)	-17,058	10,945	-4,210
Net gain (loss) on derivative contracts	($25,274)	$22,239	($6,346)

ACQUISITIONS_Details

ACQUISITIONS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Business Combinations [Abstract]	'	'	'
Acquisition costs	$2.80	$4.70	$8.90

ACQUISITIONS_Details_3

ACQUISITIONS (Details 3) (Utica Shale Assets Acquisition, USD $)	Dec. 31, 2013	Feb. 17, 2012
In Thousands, unless otherwise specified
Utica Shale Assets Acquisition	'	'
Fair value of total purchase price:	'	'
Total	$24,500	$24,800

ACQUISITIONS_Details_4

ACQUISITIONS (Details 4) (USD $)	Dec. 31, 2013	Feb. 17, 2012	Mar. 30, 2012	3-May-11	Nov. 02, 2012	Nov. 02, 2012
In Thousands, except Share data, unless otherwise specified	Utica Shale Assets Acquisition	Utica Shale Assets Acquisition	Eagle Operating, Inc.	Eagle Operating, Inc.	Viking International Resources Co., Inc	Series E Preferred Stock
						Viking International Resources Co., Inc
Acquisitions	'	'	'	'	'	'
Common stock issued in connection with acquisition (in shares)	'	'	296,859	296,859	'	2,775
Price of stock used to value stock issued in acquisition (in dollars per share)	'	'	$6.41	$6.41	'	$23.50
Cash	'	'	$50,974	'	$37,349	'
Common stock issued in connection with acquisition	'	'	1,902	'	65,209	'
Total	24,500	24,800	52,876	'	100,808	'
Amounts recognized for assets acquired and liabilities assumed:	'	'	'	'	'	'
Oil and gas properties	'	'	54,832	'	110,224	'
Asset retirement obligation	'	'	-1,956	'	-5,772	'
Total	'	'	$52,876	'	$100,808	'

ACQUISITIONS_Details_5

ACQUISITIONS (Details 5) (USD $)	Nov. 02, 2012	Mar. 30, 2012	3-May-11	Apr. 02, 2012
	Viking International Resources Co., Inc	Eagle Operating, Inc.	Eagle Operating, Inc.	Trans Tex Gas Services
				Eureka Hunter Holdings, LLC
Acquisitions	'	'	'	'
Common units acquired (in common units)	'	'	'	622,641
Fair value of total purchase price:	'	'	'	'
Total estimated enterprise value	'	'	'	$400,000,000
Stock Issued During Period, Shares, Acquisitions	'	296,859	296,859	'
Cash	37,349,000	50,974,000	'	46,047,000
Common stock issued in connection with acquisition	65,209,000	1,902,000	'	12,453,000
Escrow settlement	-1,750,000	'	'	'
Total	100,808,000	52,876,000	'	58,500,000
Amounts recognized for assets acquired and liabilities assumed:	'	'	'	'
Total working capital deficit assumed	'	'	'	525,000
Price of stock used to value stock issued in acquisition (in dollars per share)	'	$6.41	$6.41	'
Oil and gas properties	110,224,000	54,832,000	'	'
Current Assets	1,676,000	'	'	'
Equipment and other fixed assets	970,000	'	'	15,575,000
AP and accrued expenses	-3,928,000	'	'	'
Other long-term liabilities	-2,362,000	'	'	'
Asset retirement obligation	-5,772,000	-1,956,000	'	'
Other assets	'	'	'	1,306,000
Goodwill	'	'	'	30,602,000
Intangible assets	'	'	'	10,492,000
Total	$100,808,000	$52,876,000	'	$58,500,000

ACQUISITIONS_Details_6

ACQUISITIONS (Details 6) (USD $)

Dec. 20, 2012

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

22-May-12

Nov. 02, 2012

Nov. 02, 2012

Nov. 30, 2012

Nov. 02, 2012

Dec. 20, 2012

Aug. 12, 2013

Dec. 31, 2013

Dec. 17, 2013

Oct. 31, 2013

Oct. 07, 2013

Feb. 17, 2012

Apr. 02, 2012

township

Depositary shares

Depositary shares

Depositary shares

Series E Cumulative Convertible Preferred Stock

Series E Cumulative Convertible Preferred Stock

Series E Cumulative Convertible Preferred Stock

Baytex Energy USA Assets

Viking International Resources Co., Inc

Viking International Resources Co., Inc

Viking International Resources Co., Inc

Viking International Resources Co., Inc

Samson Resources Company

Utica Shale Assets Acquisition

Utica Shale Assets Acquisition

Utica Shale Assets Acquisition

Utica Shale Assets Acquisition

Utica Shale Assets Acquisition

Utica Shale Assets Acquisition

Eureka Hunter Holdings, LLC

Depositary shares

Depositary shares

Series E Cumulative Convertible Preferred Stock

acre

acre

acre

acre

Trans Tex Gas Services

Acquisitions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued in connection with acquisition (in shares)

'

'

27,906

'

'

'

'

'

'

2,774,850

2,774,850

2,774.85

'

'

'

'

'

'

'

'

Cumulative dividend rate for cumulative preferred stock (as a percent)

'

8.00%

'

8.00%

8.00%

8.00%

8.00%

'

'

'

'

8.00%

'

'

'

'

'

'

'

'

Preferred stock, liquidation preference

'

'

'

'

'

'

'

'

$69,400,000

'

'

'

'

'

'

'

'

'

'

'

Fair value of total purchase price:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash

'

'

'

'

'

'

'

312,018,000

37,349,000

'

'

'

30,000,000

'

'

'

'

'

'

46,047,000

Common units acquired (in common units)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

622,641

Common stock issued in connection with acquisition

'

'

'

'

'

'

'

'

65,209,000

'

'

'

'

'

'

'

'

'

'

12,453,000

Escrow settlement

'

'

'

'

'

'

'

'

-1,750,000

'

'

'

'

'

'

'

'

'

'

'

Total

'

'

'

'

'

'

'

312,018,000

100,808,000

'

'

'

'

'

24,500,000

'

'

'

24,800,000

58,500,000

Amounts recognized for assets acquired and liabilities assumed:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Oil and gas properties

'

'

'

'

'

'

'

312,294,000

110,224,000

'

'

'

'

'

'

'

'

'

'

'

Current Assets

'

'

'

'

'

'

'

'

1,676,000

'

'

'

'

'

'

'

'

'

'

'

Equipment and other fixed assets

'

'

'

'

'

'

'

'

970,000

'

'

'

'

'

'

'

'

'

'

15,575,000

AP and accrued expenses

'

'

'

'

'

'

'

'

-3,928,000

'

'

'

'

'

'

'

'

'

'

'

Other long-term liabilities

'

'

'

'

'

'

'

'

-2,362,000

'

'

'

'

'

'

'

'

'

'

'

Asset retirement obligation

'

'

'

'

'

'

'

-276,000

-5,772,000

'

'

'

'

'

'

'

'

'

'

'

Total

'

'

'

'

'

'

'

312,018,000

100,808,000

'

'

'

'

'

'

'

'

'

'

58,500,000

Percentage of working interest owned in acquired properties

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

Number of townships and ranges covered through acquired property

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net mineral acres acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

32,000

'

'

'

'

'

'

Maximum purchase price

'

'

'

'

'

'

'

'

'

'

'

'

'

142,100,000

'

'

'

'

'

'

Period over which acquisition takes place

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 months

'

'

'

'

'

'

Net leasehold acres purchased

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,837.64

2,050.40

1,156.14

'

'

Recognized identifiable assets acquired and liabilities assumed, land

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$10,900,000

$8,700,000

$4,900,000

'

'

ACQUISITIONS_Details_7

ACQUISITIONS (Details 7) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Eagle Operating, Inc.	'	'
Acquisitions	'	'
Revenues	$7,331	$5,500
Operating Income (Loss)	-26,867	-3,019
Trans Tex Gas Services	'	'
Acquisitions	'	'
Revenues	12,765	7,014
Operating Income (Loss)	-812	-393
Baytex Energy USA Assets	'	'
Acquisitions	'	'
Revenues	100,572	18,430
Operating Income (Loss)	-101,627	-6,649
Virco	'	'
Acquisitions	'	'
Revenues	4,453	1,094
Operating Income (Loss)	($177)	$450

ACQUISITIONS_Details_8

ACQUISITIONS (Details 8) (USD $)

3 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Business Acquisitions, Pro Forma Results Of Operations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total revenue

$54,235

$85,237

$73,032

$67,907

$45,432

$36,381

$30,598

$27,945

$280,411

$140,356

$66,455

OPERATING LOSS

-40,009

[1]

-25,839

-92,676

-26,240

-67,814

[2]

-8,898

[2]

-15,797

[2]

-15,698

[2]

-184,764

-108,207

[2]

-41,588

NET LOSS

'

'

'

'

'

'

'

'

-223,164

-136,721

-76,412

Net loss attributable to Magnum Hunter Resources Corporation

-44,197

-46,537

-296,882

165,440

-75,210

-32,463

-12,577

-12,458

-222,176

-132,708

-76,661

Net loss attributable to common shareholders

-57,685

-61,208

-311,299

151,311

-87,236

-42,283

-20,843

-17,052

-278,881

-167,414

-90,668

Loss per common share, basic and diluted

($0.34)

($1.11)

($1.83)

$0.89

($0.54)

($0.25)

($0.15)

($0.13)

($1.64)

($1.07)

($0.80)

Pro forma

'

'

'

'

'

'

'

'

'

'

'

Business Acquisitions, Pro Forma Results Of Operations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

'

159,085

'

OPERATING LOSS

'

'

'

'

'

'

'

'

'

-108,177

'

NET LOSS

'

'

'

'

'

'

'

'

'

-150,777

'

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

'

-146,764

'

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

'

($188,736)

'

Loss per common share, basic and diluted

'

'

'

'

'

'

'

'

'

($1.21)

'

[1]

The quarter-ended September 30, 2013, loss from operations was primarily driven by the loss on the sale of certain properties in Burke County, North Dakota of $38.1 million, and exploration expense. Management reviews leasehold acreage on a quarterly basis. During the quarter-ended September 30, 2013, management determined a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return.

[2]

The quarter-ended December 31, 2012, loss from operations was primarily driven by exploration expense. During the quarter-ended December 31, 2012 management determined that a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return in 2013.

GOODWILL_AND_INTANGIBLE_ASSETS2

GOODWILL AND INTANGIBLE ASSETS (Details) (USD $)	12 Months Ended			12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
				Customer relationships	Customer relationships	Trademark	Trademark	Existing contracts	Existing contracts
Intangible assets	'	'	'	'	'	'	'	'	'
Goodwill recorded related to midstream segment as a result of acquisition of the assets of TransTex Gas Services, LP	$30,600,000	'	'	'	'	'	'	'	'
Discount rate (as a percent)	13.00%	'	'	'	'	'	'	'	'
Useful lives of intangible assets	'8 years 6 months 15 days	'	'	'12 years 6 months	'	'11 years	'	'2 years 10 months 24 days	'
Intangible assets [Roll Forward]	'	'	'	'	'	'	'	'	'
Intangible assets, at beginning of the period	10,492,000	'	0	'	'	'	'	'	'
Additions acquired through acquisition	'	'	'	0	5,434,000	0	859,000	0	4,199,000
Total intangible assets	10,492,000	'	0	'	'	'	'	'	'
Accumulated amortization	'	'	'	-1,248,000	-326,000	-137,000	-58,000	-2,577,000	-1,127,000
Intangible assets, net of accumulated amortization	6,530,000	8,981,000	'	'	'	'	'	'	'
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]	'	'	'	'	'	'	'	'	'
2014	2,007,000	'	'	'	'	'	'	'	'
2015	981,000	'	'	'	'	'	'	'	'
2016	586,000	'	'	'	'	'	'	'	'
2017	519,000	'	'	'	'	'	'	'	'
2018	457,000	'	'	'	'	'	'	'	'
Thereafter	$1,980,000	'	'	'	'	'	'	'	'

ASSET_RETIREMENT_OBLIGATIONS_D

ASSET RETIREMENT OBLIGATIONS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation Disclosure [Abstract]	'	'
Asset retirement obligation at beginning of period	$30,680	$20,584
Assumed in acquisition	17	8,027
Liabilities incurred	253	373
Liabilities settled	-98	-80
Liabilities associated with assets sold	-7,614	0
Accretion expense	2,264	1,671
Revisions in estimated liabilities	1,935	76
Reclassified as liabilities associated with assets held for sale	-11,148	13
Effect of foreign currency translation	-73	16
Asset retirement obligation at end of period	16,216	30,680
Less: current portion	-53	-2,358
Asset retirement obligation at end of period	$16,163	$28,322

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

22-May-12

Dec. 31, 2013

Dec. 13, 2012

16-May-12

Dec. 31, 2013

Nov. 08, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Baytex

Exchange Notes [Member]

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Various equipment and real estate notes payable with maturity January 2015 - April 2021

Various equipment and real estate notes payable with maturity January 2015 - April 2021

Second lien term loan due August 16, 2018

Second lien term loan due August 16, 2018

Second Lien Term Loan Due October 13 2016 at 8 Percent Interest Rate [Member]

Senior Revolving Credit Facility

Senior Revolving Credit Facility

On or after May 15, 2016

After May 15, 2017

After May 15, 2018

Prior to May 15, 2016

Prior to May 15, 2016

Prior to May 15, 2016

Before May 15, 2015

Eureka Hunter Pipelines, LLC

Eureka Hunter Pipelines, LLC

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Senior Notes Payable due May 15, 2020

Option one

Option two

Notes payable disclosures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt, outstanding

$883,845,000

$890,760,000

'

'

$597,230,000

'

'

'

'

$597,212,000

$18,615,000

[1]

$18,548,000

[1]

$50,000,000

$50,000,000

'

$218,000,000

$225,000,000

'

'

'

'

'

'

'

Less: current portion

-3,967,000

-3,991,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt

879,878,000

886,769,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Assets held for sale, current portion

5,366,000

500,000

'

'

'

'

'

'

'

'

163,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Assets held for sale, long term

162,687,000

0

'

'

'

'

'

'

'

'

3,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Table of approximate annual maturities of debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2014

3,967,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2015

7,940,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2016

224,378,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2017

330,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2018

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Thereafter

597,230,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total

883,845,000

'

'

'

'

'

'

'

600,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes issued

'

'

'

'

'

150,000,000

450,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate (as a percent)

'

'

'

'

'

'

9.75%

9.75%

'

'

'

'

12.50%

12.50%

8.00%

3.56%

3.56%

'

'

'

'

'

'

'

Interest rate, low end of the range (as a percent)

'

'

'

'

'

'

'

'

'

'

4.25%

4.25%

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, high end of the range (as a percent)

'

'

'

'

'

'

'

'

'

'

5.70%

5.70%

'

'

'

'

'

'

'

'

'

'

'

'

Penalty interest paid

'

'

'

'

'

1,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuing Senior Notes

0

596,907,000

0

'

'

149,900,000

431,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuing costs of senior notes

'

'

'

'

'

3,100,000

12,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes payable, unamortized discount (in dollars)

'

'

'

'

'

'

6,000,000

2,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total

'

'

'

312,018,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Premium on Issuing Senior Notes

'

'

'

'

'

$3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum percentage of holding in senior notes

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption price on senior notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

104.88%

102.44%

100.00%

100.00%

'

'

109.75%

Make-whole premium as percentage of principle amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

Make-whole permium calculated as basis points added to treasury rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

Maximum percentage of the aggregate principal amount of notes redeemable before May 15, 2015 with net proceeds of certain equity offerings

'

'

'

'

'

'

'

35.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum percentage of the aggregate principal amount of notes redeemed, after redemption up to 35% with net proceeds of certain equity offerings

'

'

'

'

'

'

'

65.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of days within entity may redeem the notes

'

'

'

'

'

'

'

'180 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption price as percentage of principal amount of notes redeemable within 180 days of the closing date of equity offering

'

'

'

'

'

'

'

101.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Includes notes classified as liabilities associated with assets held for sale of which $163,000 is current and $3.8 million is long term

LONGTERM_DEBT_Details_2

LONG-TERM DEBT (Details 2) (USD $)	3 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2013
Notes payable disclosures	'	'
Long-term debt, principal amount, outstanding	$890,760,000	$883,845,000
Senior revolving credit facility due August 16, 2016	'	'
Notes payable disclosures	'	'
Maximum borrowing capacity	'	100,000,000
Initial committed amount	'	25,000,000
Commitment fee percentage	'	0.50%
Senior Revolving Credit Facility	'	'
Notes payable disclosures	'	'
Long-term debt, principal amount, outstanding	225,000,000	218,000,000
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Base rate	'	'
Notes payable disclosures	'	'
Variable rate basis	'	'base rate
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Base rate | Minimum	'	'
Notes payable disclosures	'	'
Variable rate spread	'	1.25%
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Base rate | Maximum	'	'
Notes payable disclosures	'	'
Variable rate spread	'	2.25%
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Prime lending rate	'	'
Notes payable disclosures	'	'
Variable rate basis	'	'prime
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Federal funds rate	'	'
Notes payable disclosures	'	'
Variable rate basis	'	'Federal Funds Rate
Variable rate spread	'	0.50%
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Adjusted LIBOR for one-month interest period	'	'
Notes payable disclosures	'	'
Variable rate spread	'	1.00%
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Adjusted LIBOR	'	'
Notes payable disclosures	'	'
Variable rate basis	'	'Adjusted LIBO Rate
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Adjusted LIBOR | Minimum	'	'
Notes payable disclosures	'	'
Variable rate spread	'	2.25%
Eureka Hunter Pipelines, LLC | Senior revolving credit facility due August 16, 2016 | Adjusted LIBOR | Maximum	'	'
Notes payable disclosures	'	'
Variable rate spread	'	3.50%
Eureka Hunter Pipelines, LLC | Swingline loan facility	'	'
Notes payable disclosures	'	'
Maximum borrowing capacity	'	5,000,000
Eureka Hunter Pipelines, LLC | Letter of credit facility	'	'
Notes payable disclosures	'	'
Maximum borrowing capacity	'	5,000,000
Eureka Hunter Pipelines, LLC | Second lien term loan due August 16, 2018	'	'
Notes payable disclosures	'	'
Maximum borrowing capacity	'	50,000,000
Increase rate of interest under default of revolver or term loan	'	2.00%
Total debt to capitalization ratio, maximum	'	60.00%
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	0.85	'
EBITDA to interest expense ratio, minimum	0.85	'
Debt under revolver to EBITDA ratio	'	3.5
Long-term debt, principal amount, outstanding	50,000,000	50,000,000
Eureka Hunter Pipelines, LLC | Second lien term loan due August 16, 2018 | Fiscal quarter ended June 30, 2013	'	'
Notes payable disclosures	'	'
Debt to EBITDA ratio, maximum	'	6
Eureka Hunter Pipelines, LLC | Second lien term loan due August 16, 2018 | Fiscal quarter ended December 31, 2013	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.25
EBITDA to interest expense ratio, minimum	'	2.25
Debt to EBITDA ratio, maximum	'	4.5
Eureka Hunter Pipelines, LLC | Second lien term loan due August 16, 2018 | Fiscal quarter ended March 31, 2014	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.25
EBITDA to interest expense ratio, minimum	'	2.25
Debt to EBITDA ratio, maximum	'	4.5
Eureka Hunter Pipelines, LLC | Second lien term loan due August 16, 2018 | Fiscal quarter ended June 30, 2014	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.5
EBITDA to interest expense ratio, minimum	'	2.5
Debt to EBITDA ratio, maximum	'	4.5
Eureka Hunter Pipelines, LLC | Second lien term loan due August 16, 2018 | Fiscal quarter ended September 30, 2014	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.5
EBITDA to interest expense ratio, minimum	'	2.5
Debt to EBITDA ratio, maximum	'	4.5
Eureka Hunter Pipelines, LLC | Second lien term loan due August 16, 2018 | Fiscal quarter ended December 31, 2014 and each fiscal quarter thereafter	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.75
EBITDA to interest expense ratio, minimum	'	2.75
Debt to EBITDA ratio, maximum	'	4.25
Eureka Hunter Pipelines, LLC | Second lien term loan due August 16, 2018 | On or after June 29, 2012	'	'
Notes payable disclosures	'	'
Interest rate to be paid in cash	'	12.50%
Interest to be paid in cash or in shares of restricted common stock when idebtedness exceeds threshold	'	13.50%
Indebtedness threshold causing increase in interest rate	'	1,000,000
Eureka Hunter Pipelines, LLC | Senior Revolving Credit Facility	'	'
Notes payable disclosures	'	'
Debt under revolver to EBITDA ratio	'	3.25
Eureka Hunter Pipelines, LLC | Senior Revolving Credit Facility | Fiscal quarter ended June 30, 2013	'	'
Notes payable disclosures	'	'
Debt to EBITDA ratio, maximum	'	5.75
Eureka Hunter Pipelines, LLC | Senior Revolving Credit Facility | Fiscal quarter ended December 31, 2013	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.5
EBITDA to interest expense ratio, minimum	'	2.5
Debt to EBITDA ratio, maximum	'	4.5
Eureka Hunter Pipelines, LLC | Senior Revolving Credit Facility | Fiscal quarter ended March 31, 2014	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.5
EBITDA to interest expense ratio, minimum	'	2.5
Debt to EBITDA ratio, maximum	'	4.5
Eureka Hunter Pipelines, LLC | Senior Revolving Credit Facility | Fiscal quarter ended June 30, 2014	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.75
EBITDA to interest expense ratio, minimum	'	2.75
Eureka Hunter Pipelines, LLC | Senior Revolving Credit Facility | Fiscal quarter ended September 30, 2014	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	2.5
EBITDA to interest expense ratio, minimum	'	2.5
Eureka Hunter Pipelines, LLC | Senior Revolving Credit Facility | Fiscal quarter ended December 31, 2014 and each fiscal quarter thereafter	'	'
Notes payable disclosures	'	'
Consolidated Earnings before Interest Taxes Depreciation Amortization to Consolidated Interest Expense Ratio, Minimum	'	3
EBITDA to interest expense ratio, minimum	'	3
Eureka Hunter Pipelines, LLC | Senior Revolving Credit Facility | Fiscal quarter ended June 30, 2014 and each fiscal quarter thereafter	'	'
Notes payable disclosures	'	'
Debt to EBITDA ratio, maximum	'	4
Senior Revolving Credit Facility | Fiscal quarter ended June 30, 2014	'	'
Notes payable disclosures	'	'
Total debt to EBITDAX ratio	'	4.5
Senior Revolving Credit Facility | Fiscal quarter ended December 31, 2014 and each fiscal quarter thereafter	'	'
Notes payable disclosures	'	'
Total debt to EBITDAX ratio	'	4.25
Senior Revolving Credit Facility | Third Amended and Restated Credit Agreement [Member]	'	'
Notes payable disclosures	'	'
Borrowing base minimum	'	242,500,000
Maximum borrowing capacity	'	750,000,000
Sublimit	'	10,000,000
Commitment fee percent of the unused portion of the borrowing base and commitments	'	0.50%
Interest rate on overdure amounts	'	2.00%
Minimum borrowing capacity as percent of borrowing base	'	2.50%
Borrowing capacity availability	'	5,000,000
Dividends preferred stock dividend basket	'	$45,000,000
Current ratio	'	1
Senior Revolving Credit Facility | Fiscal Quarter Ending Through March 31, 2014 and For Trailing Four Fiscal Quarter Period Then Ended [Member]	'	'
Notes payable disclosures	'	'
Total debt to EBITDAX ratio	'	2
Senior Revolving Credit Facility | Minimum | Third Amended and Restated Credit Agreement [Member]	'	'
Notes payable disclosures	'	'
Lien of value of proved oil and gas properties as a percent	'	80.00%
Senior Revolving Credit Facility | Maximum | Fiscal quarter ended December 31, 2013	'	'
Notes payable disclosures	'	'
EBITDAX to interest expense	'	200.00%
Senior Revolving Credit Facility | Maximum | Fiscal quarter ended March 31, 2014	'	'
Notes payable disclosures	'	'
EBITDAX to interest expense	'	225.00%
Senior Revolving Credit Facility | Maximum | Fiscal quarter ended June 30, 2014	'	'
Notes payable disclosures	'	'
EBITDAX to interest expense	'	250.00%
Senior Revolving Credit Facility | Federal funds rate | Third Amended and Restated Credit Agreement [Member]	'	'
Notes payable disclosures	'	'
Variable rate spread	'	0.50%
Senior Revolving Credit Facility | Adjusted LIBOR for one-month interest period | Third Amended and Restated Credit Agreement [Member]	'	'
Notes payable disclosures	'	'
Variable rate spread	'	1.00%
Senior Revolving Credit Facility | Alternate Base Rate [Member] | Minimum | Third Amended and Restated Credit Agreement [Member]	'	'
Notes payable disclosures	'	'
Variable rate spread	'	1.50%
Senior Revolving Credit Facility | Alternate Base Rate [Member] | Maximum | Third Amended and Restated Credit Agreement [Member]	'	'
Notes payable disclosures	'	'
Variable rate spread	'	2.25%
Senior Revolving Credit Facility | Adjusted LIBOR | Minimum | Third Amended and Restated Credit Agreement [Member]	'	'
Notes payable disclosures	'	'
Variable rate spread	'	250.00%
Senior Revolving Credit Facility | Adjusted LIBOR | Maximum | Third Amended and Restated Credit Agreement [Member]	'	'
Notes payable disclosures	'	'
Variable rate spread	'	3.25%

LONGTERM_DEBT_Details_3

LONG-TERM DEBT (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Notes payable disclosures	'	'	'
Long-term Debt, Gross	$883,845	'	'
Long-term debt, principal amount, outstanding	883,845	890,760	'
Interest expense incurred on debt, net of amounts capitalized	67,605	44,216	'
Amortization and write off of deferred financing cost and discount on Senior Notes included in interest expense	4,836	7,399	3,636
Amortization and write-off of deferred financing costs	4,818	7,400	'
Total Interest Expense	72,423	51,616	11,752
Senior Revolving Credit Facility	'	'	'
Notes payable disclosures	'	'	'
Long-term debt, principal amount, outstanding	$218,000	$225,000	'

SHAREBASED_COMPENSATION_Detail

SHARE-BASED COMPENSATION (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2009
Share-Based Compensation	'		'		'		'
Number of shares authorized under the Amended and Restated Stock Incentive Plan	27,500,000		'		'		'
Number of shares issued under the Amended and Restated Stock Incentive Plan	5,360,176		'		'		'
Share-based compensation expense	$13.60		$15.70		$25.10		'
Stock options and stock appreciation rights	'		'		'		'
Shares	'		'		'		'
Outstanding at beginning of period (in shares)	14,846,994		12,566,199		'		12,779,282
Granted (in shares)	4,937,575		4,978,750		5,601,792		'
Exercised (in shares)	-1,466,025		-1,304,050		-5,479,250		'
Forfeited or expired (in shares)	-1,427,125		-1,393,905		-335,625		'
Outstanding at end of period (in shares)	16,891,419		14,846,994		12,566,199		12,779,282
Exercisable at end of period (in shares)	9,983,743		8,683,622		6,915,471		'
Weighted Average Exercise Price	'		'		'		'
Outstanding at beginning of period (in dollars per share)	$6.01		$5.64		'		$2.65
Granted (in dollars per share)	$4.11		$6		$7.74		'
Exercised (in dollars per share)	$3.66		$1.54		$0.92		'
Cancelled (in dollars per share)	$5.51		$7.14		$3.40		'
Outstanding at end of period (in dollars per share)	$5.69		$6.01		$5.64		$2.65
Exercisable at end of period (in dollars per share)	$5.96		$5.97		$4.97		'
Non-vested Shares	'		'		'		'
Non-vested at beginning of period (in shares)	6,163,372		5,650,782		'		5,215,532
Granted (in shares)	4,937,575		4,978,750		5,601,792		'
Vested (in shares)	-3,133,700		-3,405,434		-4,832,417		'
Forfeited (in shares)	-1,059,771		-1,060,726		-334,125		'
Non-vested at end of period (in shares)	6,907,476		6,163,372		5,650,782		5,215,532
Additional disclosures	'		'		'		'
Unrecognized compensation cost	14.1		12.6		9.2		'
Weighted average period for recognition of compensation cost	'1 year 9 months 7 days		'		'		'
Intrinsic value for outstanding options	29.7		'		'		'
Remaining contractual term	'5 years 10 months 17 days		'		'		'
Common stock options | Weighted average	'		'		'		'
Assumptions used in fair value method calculation	'		'		'		'
Weighted average fair value per option granted during the period (in dollars per share)	$2.52	[1]	$3.72	[1]	$4.28	[1]	'
Weighted average stock price volatility	80.61%	[2],[3]	82.64%	[2],[3]	64.29%	[2],[3]	'
Weighted average risk free rate of return	0.78%	[2]	0.77%	[2]	2.04%	[2]	'
Weighted average estimated forfeiture rate	2.45%		0.00%		0.00%		'
Weighted average expected term	'4 years 7 months 24 days	[2]	'4 years 6 months 4 days	[2]	'6 years 4 months 10 days	[2]	'
Non-vested common shares	'		'		'		'
Additional disclosures	'		'		'		'
Unrecognized compensation cost	$0.20		$0.40		$0.80		'
Weighted average period for recognition of compensation cost	'2 years 10 months 24 days		'		'		'
Shares	'		'		'		'
Non-vested at beginning of year (in shares)	65,025		155,049		'		300,074
Granted (in shares)	210,494		69,791		40,305		'
Vested (in shares)	-248,019		-159,815		-185,330		'
Non-vested at end of year (in shares)	27,500		65,025		155,049		300,074
Weighted Average Price Per Share	'		'		'		'
Non-vested at beginning of year, weighted average exercise price	$6.09		$4.43		'		$4.43
Granted (in dollars per share)	$4.66		$4.29		$5.45		'
Vested (in dollars per share)	$4.75		$4.46		$0.47		'
Non-vested at end of year, weighted average exercise price	$7.24		$6.09		$4.43		$4.43
Board of Directors [Member] | Non-vested common shares	'		'		'		'
Shares	'		'		'		'
Granted (in shares)	182,994		'		'		'
[1]	Calculated using the Black-Scholes fair value based method for service and performance based grants and the Lattice Model for market based grants.
[2]	The Company has not paid dividends on our common stock.
[3]	The volatility assumption was estimated based upon a blended calculation of historical volatility and implied volatility over the life of the awards.

SHAREHOLDERS_EQUITY_Details

SHAREHOLDERS' EQUITY (Details) (USD $)

9 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

1 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2009

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2006

Nov. 16, 2009

Nov. 05, 2009

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Aug. 13, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jan. 14, 2011

Apr. 13, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

3-May-11

Mar. 30, 2012

Nov. 30, 2012

Nov. 02, 2012

Dec. 31, 2008

Dec. 31, 2011

Sep. 16, 2013

Aug. 26, 2013

Sep. 30, 2013

Aug. 13, 2011

Aug. 13, 2013

Aug. 20, 2012

Aug. 13, 2011

Dec. 31, 2013

Aug. 13, 2013

16-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Aug. 13, 2011

3-May-11

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 13, 2009

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Sep. 07, 2012

Dec. 31, 2011

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Nov. 02, 2012

Nov. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 02, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Nov. 02, 2012

$3.00 common stock warrants

$3.00 common stock warrants

$3.00 common stock warrants

$2.50 Common stock warrants

$2.50 Common stock warrants

$2.50 Common stock warrants

$2.50 Common stock warrants

$2.00 common stock warrants

$10.50 Common stock warrants

$10.50 Common stock warrants

$15.13 Common stock warrants

$19.04 Common stock warrants

PostRock

NGAS Resources, Inc.

NGAS Resources, Inc.

NGAS Resources, Inc.

NGAS Resources, Inc.

NuLoch Resources

Eagle Operating

VIRCO

VIRCO

PRC Williston, Inc.

At the market sales agreement

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Exchangeable common stock

Exchangeable common stock

Exchangeable common stock

Exchangeable common stock

Exchangeable common stock

Exchangeable common stock

Exchangeable common stock

Exchangeable common stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Depositary shares

Depositary shares

Depositary shares

Depositary shares

Depositary shares

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

warrant

warrant

warrant

warrant

warrant

$10.50 Common stock warrants

Magnum Hunter Resources Corporation

Magnum Hunter Resources Corporation

Magnum Hunter Resources Corporation

Magnum Hunter Resources Corporation

Magnum Hunter Resources Corporation

Underwritten public offering

$10.50 Common stock warrants

NuLoch Resources

NuLoch Resources

NuLoch Resources

NuLoch Resources

At the market sales agreement

At the market sales agreement

At the market sales agreement

At the market sales agreement

Underwritten public offering

Underwritten public offering

VIRCO

VIRCO

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

VIRCO

warrant

Minimum

warrant

discretionary_contribution

Class of Stock [Line Items]

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Preferred Stock, Interest in Series E Preferred Stock per Share

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0.001

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Dividends, Ratio of Warrants Received per Common Stock

'

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10.00%

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Common Stock [Abstract]

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Common stock issued in connection with share-based compensation (in shares)

'

182,994

84,052

121,143

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Common stock issued upon warrant exercise (in shares)

'

1,466,025

1,438,275

6,293,107

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Proceeds from exercise of common stock options

'

$5,400,000

$2,300,000

$7,600,000

'

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Stock issued (in shares)

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1,713,598

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35,000,000

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'

216,068

'

2,771,263

1,437,558

1,721,263

1,037,558

1,050,000

400,000

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$8.27

'

'

'

'

'

'

'

'

'

$4.50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$44

'

'

$24.24

$23.50

'

'

'

'

'

'

'

'

'

'

'

'

'

Total new proceeds from issuance of common stock

'

0

148,241,000

13,892,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued in connection with acquisition (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

946,314

6,635,478

'

'

'

38,131,846

296,859

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,906

'

2,774,850

2,774,850

'

'

'

'

'

'

'

'

'

'

2,774.85

Common stock issued in connection with acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,500,000

53,017,000

'

'

'

282,175,000

1,900,000

'

65,209,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued in connection with acquisition (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$7.97

$7.99

'

'

'

$7.40

$6.41

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$23.50

Common stock issued upon exchange of MHR Exchangeco Corporation's exchangeable shares (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

505,835

3,188,036

582,127

'

'

3,188,036

582,127

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued to employees in connection with acquisition (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

350,626

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued to employees in connection with acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from stock issuance

'

10,072,000

144,635,000

94,764,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

157,500,000

'

'

'

'

'

'

'

'

5,100,000

'

'

'

29,100,000

63,400,000

9,600,000

'

122,500,000

'

77,900,000

'

44,600,000

'

'

590,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gross proceeds from stock issuance

'

'

148,241,000

13,892,000

'

328,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued as a matching contribution to the Employee Stock Ownership Plan (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

221,170

199,055

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Obligation to make future contributions to the plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unearned Common Stock in Employee Stock Ownership Plan [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares returned to treasury

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

153,300

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Treasury stock (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$3.94

'

'

$3.94

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock to be offered for sale or contributed to the Plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

153,300

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of discretionary matching contributions common stock may be contributed (one or more)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exchangeable Common Stock [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exchangeable shares issued for acquisition of NuLoch Resources (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,275,998

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares of common stock exchaged by each exchangeable share

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exchangeable shares issued for acquisition of NuLoch Resources

'

'

'

31,643,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exchangeable stock, time period from issuance the shares are redeemable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock Warrants [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of warrants exercised

'

'

'

'

'

48

771,812

871,500

'

'

134,177

42,045

'

'

13,237,889

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercise price of warrants (in dollars per share)

'

'

'

'

'

10.5

3

3

2.5

2.5

2.5

2.5

3

10.5

10.5

15.13

19.04

'

'

'

'

'

'

'

'

'

'

'

'

8.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Warrants Fair Value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term of warrants

'

'

'

'

'

'

'

'5 years

'3 years

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants issued along with a cash payment for commission fees

'

'

'

'

'

'

'

326,812

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercise price in conjuncction with private placement

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants issued in association with common stock sales

'

'

'

'

'

'

'

'

1,280,744

457,982

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of common shares that can be purchased upon exercise of warrant

'

'

'

'

'

'

'

'

'

1

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption price of warrants (in dollars per share)

'

'

'

'

'

'

'

'

'

0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.001

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right Number Of Days Notice Required For Redemption By Company

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum average trading price of common stock

'

'

'

'

'

'

'

'

'

$3.75

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Threshold number of specified trading days that common stock price must exceed threshold price within a specified consecutive trading period to trigger redemption event

'

'

'

'

'

'

'

'

'

'20 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares that can be purchased from exercise of each warrant

'

'

'

'

'

'

'

'

1,280,744

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercise price as a percentage of closing price of common shares

'

'

'

'

'

'

'

'

145.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,609,038

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exchange ratio of NGAS warrants into common stock warrants

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.46%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period available to holder under cash out option

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash paid on cash out option on warrants

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants opted cash out option (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

251,536

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants convertible outstanding (in shares)

'

138,388

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of warrants to common stock holders (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,875,093

'

'

'

'

'

'

'

'

'

378,174

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair market value of warrants

'

'

'

'

'

'

'

'

'

'

'

'

'

6,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Warrants Issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,030,622

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from exercise of warrants

'

'

'

2,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants expired (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

15,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock warrants canceled during the year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,330

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Changes in warrant activity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares, Outstanding at beginning of year

13,376,277

13,376,277

13,525,832

'

963,034

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares, Granted

'

17,030,622

0

13,391,655

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares, Exercised, forfeited, or expired

'

-13,237,889

-149,555

-828,857

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares, Outstanding at end of year

'

17,169,010

13,376,277

13,525,832

963,034

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares, Exercisable at end of year

'

17,169,010

13,376,277

13,525,832

'

'

'

'

'

'

'

'

'

'

'

97,780

40,608

'

389,924

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Changes in weighted-average exercise price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-Average Exercise Price, Outstanding at beginning of period (in dollars per share)

10.56

10.56

10.48

'

2.91

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-Average Exercise Price, Granted

'

8.5

0

10.56

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-Average Exercise Price, Exercised, forfeited, or expired (in dollars per share)

'

10.5

3.32

2.97

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-Average Exercise Price, Outstanding at end of period (in dollars per share)

'

8.56

10.56

10.48

2.91

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-Average Exercise Price, Exercisable at end of year (in dollars per share)

'

8.56

10.56

10.48

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants outstanding

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average remaining contract life

'

'9 months 18 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cumulative Perpetual Preferred Stock [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cumulative dividend rate for cumulative preferred stock (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.25%

'

'

'

'

'

8.00%

8.00%

8.00%

'

'

'

'

8.00%

'

8.00%

'

'

'

'

'

'

'

'

8.00%

8.00%

8.00%

'

8.00%

Preferred stock par value (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

'

'

'

'

'

'

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

'

Preferred Stock, liquidation preference (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$50

$50

$50

'

'

'

'

'

'

$25

'

'

'

'

'

'

'

'

$25,000

$25,000

$25,000

'

'

Issued shares of Preferred Stock for cash

'

10,181,000

144,635,000

65,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Offering expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,212,263

'

3,100,000

'

1,500,000

'

1,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Conversion price (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$8.50

'

'

'

'

'

'

'

'

'

$8.50

'

'

'

Depositary share issued into escrow account related to acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

70,000

'

'

'

'

'

'

'

'

'

'

'

Percentage of ownership interest acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Depositary shares returned and held in treasury

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of depositary shares (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$22.44

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-controlling Interests [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-controlling interest acquired

'

497,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity participation agreement, percentage of distributions paid to PRC Williston payable to lenders

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value of equity participation agreements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common units issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

214,950

4,000,000

4,000,000

'

1,190,544

2,594,506

'

'

'

'

'

'

'

'

'

'

'

'

'

9,885,048

7,672,892

'

'

'

622,641

'

'

'

'

'

Value of common units issued related to acquisitions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,500,000

'

'

'

'

'

Summary of Non-controlling Interests [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-controlling interest at beginning of period

10,139,000

10,139,000

2,196,000

'

1,450,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-controlling interests acquired through acquisition of NGAS

'

'

12,453,000

497,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

0

497,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase of outstanding non-controlling interests

'

0

-497,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of shares of Eureka Hunter Holdings, LLC Common Units

'

0

12,453,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income (loss) attributable to non-controlling interest

'

-988,000

-4,013,000

249,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other

'

-1,000

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-controlling interest at end of period

'

9,150,000

10,139,000

2,196,000

1,450,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends, Preferred Stock [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends on preferred stock

'

-49,787,000

-30,931,000

-14,007,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-10,248,000

-10,248,000

-10,248,000

'

'

'

-17,655,000

-11,699,000

-3,759,000

'

'

'

'

'

'

'

'

'

'

'

-14,323,000

-8,090,000

0

'

'

-7,561,000

-894,000

0

'

Accretion of the difference between the carrying value and the redemption value of preferred stock included in dividends

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$6,900,000

$3,800,000

$0

'

'

'

'

'

'

REEDEMABLE_PREFERRED_STOCK_Det

REEDEMABLE PREFERRED STOCK (Details) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 13, 2009

Dec. 31, 2013

Dec. 31, 2012

Dec. 14, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 02, 2012

Mar. 21, 2012

Dec. 31, 2013

Dec. 31, 2012

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

At the market sales agreement

At the market sales agreement

Maximum

Maximum

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Ridgeline

Ridgeline

Ridgeline

March 31, 2012 through March 31, 2013

June 30, 2013 through March 31, 2014

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, shares issued

'

'

'

214,950

4,000,000

4,000,000

'

1,190,544

2,594,506

9,885,048

7,672,892

'

'

'

622,641

'

1,800,000

7,590,000

Temporary Equity Dividend Rate Percentage

'

'

'

10.25%

10.25%

10.25%

'

'

'

8.00%

8.00%

'

'

8.00%

'

'

'

'

Preferred stock par value per share

'

'

'

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, liquidation preference (in dollars per share)

'

'

'

$25

$25

$25

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from stock issuance

$10,072,000

$144,635,000

$94,764,000

$5,100,000

'

'

'

$29,100,000

$63,400,000

'

'

'

'

'

'

'

$35,300,000

$148,600,000

Preferred stock, redemption price per share at the Company's option

'

'

'

'

'

'

$25

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, redemption price per share in the event of a change of control

'

'

'

'

$25

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, shares authorized

'

'

'

'

4,000,000

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, maximum purchase commitment pursuant to Unit Purchase Agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000,000

'

'

Percentage ownership of Eureka Holdings by non-controlling owners

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

41.70%

'

Cumulative dividend rate for cumulative preferred stock increased (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

Percentage of dividend owed paid in kind

'

'

'

'

'

'

'

'

'

'

'

75.00%

50.00%

'

'

'

'

'

Threshold conversion ratio (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

Conversion ratio (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

Fair value of embedded derivative liability

'

'

'

'

'

'

'

'

'

75,900,000

0

'

'

'

'

'

'

'

Preferred stock, cash dividends paid

56,705,000

34,706,000

14,007,000

'

'

'

'

'

'

5,200,000

'

'

'

'

'

'

'

'

Preferred stock, dividends accrued

'

'

'

'

'

'

'

'

'

3,900,000

'

'

'

'

'

'

'

'

Preferred stock, dividends paid-in-kind

$8,243,000

$1,658,000

'

'

'

'

'

'

'

$8,200,000

'

'

'

'

'

'

'

'

Preferred stock issued as in-kind payment (in shares)

'

'

'

'

'

'

'

'

'

412,157

'

'

'

'

'

'

'

'

Preferred Stock, shares outstanding

'

'

'

'

'

'

'

'

'

9,885,048

'

'

'

'

'

'

'

'

INCOME_TAXES_Details

INCOME TAXES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2009
Deferred income tax expense (benefit)	'	'	'	'
U.S. federal	($63,629,000)	($15,109,000)	($1,025,000)	'
Various states	-6,668,000	-4,203,000	-1,837,000	'
Total deferred tax expense (benefit)	-70,297,000	-19,312,000	-2,862,000	'
Total income tax expense (benefit)	-70,297,000	-19,312,000	-2,862,000	'
Reconciliation of income tax expense (benefit)	'	'	'	'
Income tax benefit at statutory U.S. rate	-96,022,000	-48,639,000	-20,887,000	'
State income taxes (net of federal benefit)	-4,334,000	-2,732,000	-1,194,000	'
Tax effect of permanent differences	750,000	-555,000	419,000	'
Tax effect of loss attributable to non-controlled interest	346,000	797,000	0	'
Tax benefit recognized as tax expense in discontinued operations	-13,879,000	7,000	0	'
Change in valuation allowance	43,232,000	31,810,000	18,800,000	'
Other	-390,000	0	0	'
Total continuing operations	-70,297,000	-19,312,000	-2,862,000	'
Discontinued operations	-3,336,000	-2,283,000	2,166,000	'
Total tax benefit	-73,633,000	-21,595,000	-696,000	'
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest [Abstract]	'	'	'	'
Domestic	-274,349,000	-138,968,000	-59,676,000	'
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-274,349,000	-138,968,000	-59,676,000	'
Loss from discontinued operations	-75,838,000	-23,053,000	-17,432,000	'
Gain on disposal of discontinued operations	53,389,000	3,706,000	0	'
Loss before income tax	-296,798,000	-158,315,000	-77,108,000	'
Deferred tax assets:	'	'	'	'
Net operating loss carry forwards	155,507,000	193,310,000	62,923,000	'
Share-based compensation	10,156,000	7,950,000	10,247,000	'
Depletion carryforwards	1,047,000	997,000	972,000	'
Tax credits	53,000	53,000	26,340,000	'
US investment in Canada	74,148,000	0	0	'
Other	561,000	532,000	7,475,000	'
Deferred tax liabilities:	'	'	'	'
Property and equipment	-90,950,000	-206,650,000	-111,015,000	'
Valuation allowances	'	'	'	'
Valuation allowance	-150,522,000	-70,450,000	-92,241,000	'
Net deferred tax	0	-74,258,000	-95,299,000	'
Non-current deferred tax asset (liability)	0	-74,258,000	'	'
Net deferred tax	0	-74,258,000	-95,299,000	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'	'	'	'
Unrecognized tax benefits at January 1	3,879,000	0	'	0
Change in unrecognized tax benefits taken during a prior period	0	0	0	'
Change in unrecognized tax benefits taken during the current period (netted against the US net operating loss)	0	3,879,000	0	'
Decreases in unrecognized tax benefits from settlements with taxing authorities	0	0	0	'
Reductions to unrecognized tax benefits from lapse of statutes of limitations	0	0	0	'
Unrecognized tax benefits at December 31	3,879,000	3,879,000	0	0
NOL from excess stock based compensation deductions	'	'	'	'
Deferred income tax expense (benefit)	'	'	'	'
Net operating loss carry forwards	22,400,000	'	'	'
Deferred tax assets:	'	'	'	'
Net operating loss carry forwards	8,300,000	'	'	'
U.S. federal income tax	'	'	'	'
Deferred income tax expense (benefit)	'	'	'	'
Net operating loss carry forwards	400,000,000	'	'	'
Depletion carryover	2,800,000	'	'	'
Depletion carryover, tax effected	1,100,000	'	'	'
Foreign	'	'	'	'
Deferred income tax expense (benefit)	'	'	'	'
Net operating loss carry forwards	$66,400,000	'	'	'

MAJOR_CUSTOMERS_Details

MAJOR CUSTOMERS (Details) (Revenues, Customer concentration)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Samson Resources Company	'	'	'
Major customers	'	'	'
Concentration percentage	36.00%	17.00%	10.00%
Baytex Energy USA LTD	'	'	'
Major customers	'	'	'
Concentration percentage	10.00%	15.00%	3.00%
Teneska Marketing Ventures	'	'	'
Major customers	'	'	'
Concentration percentage	9.00%	14.00%	14.00%
South Jersey	'	'	'
Major customers	'	'	'
Concentration percentage	5.00%	14.00%	10.00%
Plains Marketing, LP	'	'	'
Major customers	'	'	'
Concentration percentage	4.00%	11.00%	16.00%
Clearfield Energy	'	'	'
Major customers	'	'	'
Concentration percentage	1.00%	7.00%	16.00%
Ergon Oil	'	'	'
Major customers	'	'	'
Concentration percentage	3.00%	5.00%	13.00%

SUPPLEMENTAL_CASH_FLOW_INFORMA2

SUPPLEMENTAL CASH FLOW INFORMATION (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other Significant Noncash Transactions [Line Items]	'	'	'
Cash paid for interest	$70,366	$40,069	$7,952
Cash paid for taxes	1,200	0	0
Non-cash transactions	'	'	'
Change in accrued capital expenditures - increase (decrease)	-65,634	34,621	81,136
Eureka Hunter Holdings, LLC Series A convertible preferred unit dividends paid in kind	8,243	1,658	'
Non-cash additions to asset retirement obligation	2,132	8,492	12,628
Common stock issued for 401k matching contributions	1,192	874	0
Preferred stock issued for acquisitions	'	64,968	'
Eureka Hunter Holdings, LLC Class A common units issued for an acquisition	0	12,453	0
Non-cash consideration received from sale of assets	42,300	7,120	'
Common stock issued for acquisitions	'	1,902	345,537
Debt assumed in acquisitions	0	0	71,895
Exchangeable common stock issued for acquisition of NuLoch Resources	0	0	31,642
Common stock issued for payment of services	0	0	779
Dividends on MHR Exchangeco Corporation's exchangeable common stock in the form of 378,174 warrants with fair market value of $197 thousand	0	0	197
Dividend Paid | Common Stock	'	'	'
Non-cash transactions	'	'	'
Common stock dividends issued in the form of warrants	17,030,622	'	12,875,093
Fair value of warrants issued as dividends on common stock	21,600	'	0
Dividend Paid | Exchangeable common stock	'	'	'
Non-cash transactions	'	'	'
Common stock dividends issued in the form of warrants	'	'	378,174
Fair value of warrants issued as dividends on common stock	'	'	$197

OTHER_INFORMATION_Details

OTHER INFORMATION (Details) (USD $)

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

Sep. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Properties in Burke County, North Dakota [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Magnum Hunter Production and Williston Hunter Canada [Member]

Details of unaudited summary financial results

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

$54,235,000

$85,237,000

$73,032,000

$67,907,000

$45,432,000

$36,381,000

$30,598,000

$27,945,000

$280,411,000

$140,356,000

$66,455,000

'

'

'

'

'

'

Operating gain (loss)

'

-40,009,000

[1]

-25,839,000

-92,676,000

-26,240,000

-67,814,000

[2]

-8,898,000

[2]

-15,797,000

[2]

-15,698,000

[2]

-184,764,000

-108,207,000

[2]

-41,588,000

'

'

'

'

'

'

Income (loss) from continuing operations

'

-61,544,000

-10,257,000

-132,598,000

347,000

-57,172,000

-31,313,000

-8,638,000

-22,533,000

-204,052,000

-119,656,000

-56,814,000

'

'

'

'

'

'

Income from discontinued operations, net of tax

'

16,845,000

[3]

324,000

[3]

-80,554,000

[3]

-7,746,000

[3]

-22,306,000

-1,102,000

-1,789,000

5,723,000

-71,131,000

[3]

-19,474,000

-19,598,000

'

'

'

'

'

'

Net loss attributable to Magnum Hunter Resources Corporation

'

-44,197,000

-46,537,000

-296,882,000

165,440,000

-75,210,000

-32,463,000

-12,577,000

-12,458,000

-222,176,000

-132,708,000

-76,661,000

'

'

'

'

'

'

Gain on disposal of discontinued operations, net of tax

'

0

[4]

-35,979,000

[4]

-84,454,000

[4]

172,452,000

[4]

185,000

0

-2,101,000

4,325,000

52,019,000

[4],[5],[6]

2,409,000

[5],[6]

0

[5],[6]

'

'

'

92,400,000

'

'

Net loss attributable to common shareholders

'

-57,685,000

-61,208,000

-311,299,000

151,311,000

-87,236,000

-42,283,000

-20,843,000

-17,052,000

-278,881,000

-167,414,000

-90,668,000

'

'

'

'

'

'

Loss from continuing operations per share, basic and diluted

'

($0.36)

($0.06)

($0.86)

$0

($0.34)

($0.19)

($0.06)

($0.17)

($1.53)

($0.96)

($0.63)

'

'

'

'

'

'

Loss per common share, basic and diluted

'

($0.34)

($1.11)

($1.83)

$0.89

($0.54)

($0.25)

($0.15)

($0.13)

($1.64)

($1.07)

($0.80)

'

'

'

'

'

'

Loss on the sale of certain properties

'

'

'

'

'

'

'

'

'

'

'

'

38,100,000

'

'

'

'

'

Impairment expense related to discontinued operations

$72,500,000

'

'

'

'

'

'

'

'

'

'

'

'

$27,600,000

$64,800,000

$78,500,000

$324,000

$0

[1]

The quarter-ended September 30, 2013, loss from operations was primarily driven by the loss on the sale of certain properties in Burke County, North Dakota of $38.1 million, and exploration expense. Management reviews leasehold acreage on a quarterly basis. During the quarter-ended September 30, 2013, management determined a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return.

[2]

The quarter-ended December 31, 2012, loss from operations was primarily driven by exploration expense. During the quarter-ended December 31, 2012 management determined that a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return in 2013.

[3]

The quarter-ended September 30, 2013, loss from discontinued operations was primarily driven by impairment expense of $72.5 million, as management determined a significant portion of the non-core acreage would not be utilized.

[4]

The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".

[5]

Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.

[6]

The Companybs effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.

OTHER_INFORMATION_Details_2

OTHER INFORMATION (Details 2) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information

'

'

'

'

'

'

'

'

'

'

'

Oil and gas sales

'

'

'

'

'

'

'

'

$197,599

$114,659

$58,726

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

60,632

13,040

494

Oilfield services

'

'

'

'

'

'

'

'

18,431

12,333

7,149

Other revenue

'

'

'

'

'

'

'

'

3,749

324

86

Total revenue

54,235

85,237

73,032

67,907

45,432

36,381

30,598

27,945

280,411

140,356

66,455

Lease operating expenses

'

'

'

'

'

'

'

'

53,961

26,839

14,998

Severance taxes and marketing

'

'

'

'

'

'

'

'

17,721

7,854

5,341

Exploration

'

'

'

'

'

'

'

'

97,342

78,221

2,605

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

52,099

8,028

373

Oilfield services

'

'

'

'

'

'

'

'

14,825

10,037

6,759

Impairment of proved oil and gas properties

'

'

'

'

'

'

'

'

9,968

3,772

0

Depreciation, depletion, amortization and accretion

'

'

'

'

'

'

'

'

99,198

59,730

23,246

Loss on sale of assets

'

'

'

'

'

'

'

'

44,654

628

361

General and administrative

'

'

'

'

'

'

'

'

75,407

53,454

54,360

Total expenses

'

'

'

'

'

'

'

'

465,175

248,563

108,043

OPERATING LOSS

-40,009

[1]

-25,839

-92,676

-26,240

-67,814

[2]

-8,898

[2]

-15,797

[2]

-15,698

[2]

-184,764

-108,207

[2]

-41,588

Interest income

'

'

'

'

'

'

'

'

220

199

10

Interest Expense

'

'

'

'

'

'

'

'

-72,423

-51,616

-11,752

Gain (loss) on derivative contracts, net

'

'

'

'

'

'

'

'

-25,274

22,239

-6,346

Other income (expense)

'

'

'

'

'

'

'

'

7,892

-1,583

0

Total other expense

'

'

'

'

'

'

'

'

-89,585

-30,761

-18,088

Loss from continuing operations before income tax

'

'

'

'

'

'

'

'

-274,349

-138,968

-59,676

Income tax benefit (expense)

'

'

'

'

'

'

'

'

70,297

19,312

2,862

Income (loss) from continuing operations

-61,544

-10,257

-132,598

347

-57,172

-31,313

-8,638

-22,533

-204,052

-119,656

-56,814

Income (loss) from discontinued operations

16,845

[3]

324

[3]

-80,554

[3]

-7,746

[3]

-22,306

-1,102

-1,789

5,723

-71,131

[3]

-19,474

-19,598

Gain (loss) on disposal of discontinued operations

0

[4]

-35,979

[4]

-84,454

[4]

172,452

[4]

185

0

-2,101

4,325

52,019

[4],[5],[6]

2,409

[5],[6]

0

[5],[6]

Net income (loss)

'

'

'

'

'

'

'

'

-223,164

-136,721

-76,412

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

988

4,013

-249

Net loss attributable to Magnum Hunter Resources Corporation

-44,197

-46,537

-296,882

165,440

-75,210

-32,463

-12,577

-12,458

-222,176

-132,708

-76,661

Dividends on preferred stock

'

'

'

'

'

'

'

'

-56,705

-34,706

-14,007

Net loss attributable to common shareholders

-57,685

-61,208

-311,299

151,311

-87,236

-42,283

-20,843

-17,052

-278,881

-167,414

-90,668

Total segment assets

'

2,198,632

'

'

1,168,760

'

'

'

1,856,651

2,198,632

1,168,760

Segment capital expenditures

'

'

'

'

'

'

'

'

631,511

568,610

291,942

U.S. Upstream

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information

'

'

'

'

'

'

'

'

'

'

'

Oil and gas sales

'

'

'

'

'

'

'

'

197,599

114,659

58,726

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

2

0

0

Oilfield services

'

'

'

'

'

'

'

'

23

0

0

Other revenue

'

'

'

'

'

'

'

'

3,747

99

65

Total revenue

'

'

'

'

'

'

'

'

201,371

114,758

58,791

Lease operating expenses

'

'

'

'

'

'

'

'

62,675

30,429

17,194

Severance taxes and marketing

'

'

'

'

'

'

'

'

17,721

7,854

5,341

Exploration

'

'

'

'

'

'

'

'

97,342

78,221

2,605

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

2

0

0

Oilfield services

'

'

'

'

'

'

'

'

-10

0

0

Impairment of proved oil and gas properties

'

'

'

'

'

'

'

'

9,968

3,772

0

Depreciation, depletion, amortization and accretion

'

'

'

'

'

'

'

'

84,526

52,332

20,913

Loss on sale of assets

'

'

'

'

'

'

'

'

44,642

278

861

General and administrative

'

'

'

'

'

'

'

'

14,255

21,789

2,255

Total expenses

'

'

'

'

'

'

'

'

331,121

194,675

49,169

OPERATING LOSS

'

'

'

'

'

'

'

'

-129,750

-79,917

9,622

Interest income

'

'

'

'

'

'

'

'

219

197

6

Interest Expense

'

'

'

'

'

'

'

'

-7,208

-13,053

-2,071

Gain (loss) on derivative contracts, net

'

'

'

'

'

'

'

'

-185

129

0

Other income (expense)

'

'

'

'

'

'

'

'

-340

-882

0

Total other expense

'

'

'

'

'

'

'

'

-7,514

-13,609

-2,065

Loss from continuing operations before income tax

'

'

'

'

'

'

'

'

-137,264

-93,526

7,557

Income tax benefit (expense)

'

'

'

'

'

'

'

'

41,308

19,312

1,637

Income (loss) from continuing operations

'

'

'

'

'

'

'

'

-95,956

-74,214

9,194

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

5,293

6,661

-21,848

Gain (loss) on disposal of discontinued operations

'

'

'

'

'

'

'

'

125,871

2,409

0

Net income (loss)

'

'

'

'

'

'

'

'

35,208

-65,144

-12,654

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

4,173

-249

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

35,208

-60,971

-12,903

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

35,208

-60,971

-12,903

Total segment assets

'

1,602,022

'

'

797,674

'

'

'

1,373,041

1,602,022

797,674

Segment capital expenditures

'

'

'

'

'

'

'

'

489,702

417,431

202,818

Canadian Upstream

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information

'

'

'

'

'

'

'

'

'

'

'

Oil and gas sales

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

0

0

0

Oilfield services

'

'

'

'

'

'

'

'

0

0

0

Other revenue

'

'

'

'

'

'

'

'

0

0

0

Total revenue

'

'

'

'

'

'

'

'

0

0

0

Lease operating expenses

'

'

'

'

'

'

'

'

0

0

0

Severance taxes and marketing

'

'

'

'

'

'

'

'

0

0

0

Exploration

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

0

0

0

Oilfield services

'

'

'

'

'

'

'

'

0

0

0

Impairment of proved oil and gas properties

'

'

'

'

'

'

'

'

0

0

0

Depreciation, depletion, amortization and accretion

'

'

'

'

'

'

'

'

0

0

0

Loss on sale of assets

'

'

'

'

'

'

'

'

0

0

0

General and administrative

'

'

'

'

'

'

'

'

0

0

0

Total expenses

'

'

'

'

'

'

'

'

0

0

0

OPERATING LOSS

'

'

'

'

'

'

'

'

0

0

0

Interest income

'

'

'

'

'

'

'

'

0

0

0

Interest Expense

'

'

'

'

'

'

'

'

0

0

0

Gain (loss) on derivative contracts, net

'

'

'

'

'

'

'

'

0

0

0

Other income (expense)

'

'

'

'

'

'

'

'

0

0

0

Total other expense

'

'

'

'

'

'

'

'

0

0

0

Loss from continuing operations before income tax

'

'

'

'

'

'

'

'

0

0

0

Income tax benefit (expense)

'

'

'

'

'

'

'

'

0

0

697

Income (loss) from continuing operations

'

'

'

'

'

'

'

'

0

0

697

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

-76,355

-25,021

1,855

Gain (loss) on disposal of discontinued operations

'

'

'

'

'

'

'

'

-73,852

0

0

Net income (loss)

'

'

'

'

'

'

'

'

-150,207

-25,021

2,552

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-150,207

-25,021

2,552

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-150,207

-25,021

2,552

Total segment assets

'

392,918

'

'

349,410

'

'

'

68,367

392,918

349,410

Segment capital expenditures

'

'

'

'

'

'

'

'

31,025

84,536

18,493

Midstream

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information

'

'

'

'

'

'

'

'

'

'

'

Oil and gas sales

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

69,306

15,469

1,978

Oilfield services

'

'

'

'

'

'

'

'

0

0

0

Other revenue

'

'

'

'

'

'

'

'

0

223

12

Total revenue

'

'

'

'

'

'

'

'

69,306

15,692

1,990

Lease operating expenses

'

'

'

'

'

'

'

'

0

0

0

Severance taxes and marketing

'

'

'

'

'

'

'

'

0

0

0

Exploration

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

52,097

7,908

373

Oilfield services

'

'

'

'

'

'

'

'

0

0

0

Impairment of proved oil and gas properties

'

'

'

'

'

'

'

'

0

0

0

Depreciation, depletion, amortization and accretion

'

'

'

'

'

'

'

'

12,318

5,963

1,789

Loss on sale of assets

'

'

'

'

'

'

'

'

8

-250

-500

General and administrative

'

'

'

'

'

'

'

'

8,400

3,798

850

Total expenses

'

'

'

'

'

'

'

'

72,823

17,419

2,512

OPERATING LOSS

'

'

'

'

'

'

'

'

-3,517

-1,727

-522

Interest income

'

'

'

'

'

'

'

'

0

0

0

Interest Expense

'

'

'

'

'

'

'

'

-4,351

-758

-1,673

Gain (loss) on derivative contracts, net

'

'

'

'

'

'

'

'

-17,742

8,692

0

Other income (expense)

'

'

'

'

'

'

'

'

-265

-546

0

Total other expense

'

'

'

'

'

'

'

'

-22,358

7,388

-1,673

Loss from continuing operations before income tax

'

'

'

'

'

'

'

'

-25,875

5,661

-2,195

Income tax benefit (expense)

'

'

'

'

'

'

'

'

0

0

0

Income (loss) from continuing operations

'

'

'

'

'

'

'

'

-25,875

5,661

-2,195

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

0

0

0

Gain (loss) on disposal of discontinued operations

'

'

'

'

'

'

'

'

0

0

0

Net income (loss)

'

'

'

'

'

'

'

'

-25,875

5,661

-2,195

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

-160

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-25,875

5,501

-2,195

Dividends on preferred stock

'

'

'

'

'

'

'

'

-21,241

-11,864

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-47,116

-6,363

-2,195

Total segment assets

'

245,207

'

'

83,847

'

'

'

296,739

245,207

83,847

Segment capital expenditures

'

'

'

'

'

'

'

'

87,048

57,010

54,748

Oil Field Services

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information

'

'

'

'

'

'

'

'

'

'

'

Oil and gas sales

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

0

0

0

Oilfield services

'

'

'

'

'

'

'

'

21,525

13,552

9,417

Other revenue

'

'

'

'

'

'

'

'

2

0

9

Total revenue

'

'

'

'

'

'

'

'

21,527

13,552

9,426

Lease operating expenses

'

'

'

'

'

'

'

'

0

0

0

Severance taxes and marketing

'

'

'

'

'

'

'

'

0

0

0

Exploration

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

0

0

0

Oilfield services

'

'

'

'

'

'

'

'

17,914

10,420

8,315

Impairment of proved oil and gas properties

'

'

'

'

'

'

'

'

0

0

0

Depreciation, depletion, amortization and accretion

'

'

'

'

'

'

'

'

2,354

967

544

Loss on sale of assets

'

'

'

'

'

'

'

'

4

600

0

General and administrative

'

'

'

'

'

'

'

'

1,338

418

461

Total expenses

'

'

'

'

'

'

'

'

21,610

12,405

9,320

OPERATING LOSS

'

'

'

'

'

'

'

'

-83

1,147

106

Interest income

'

'

'

'

'

'

'

'

0

0

0

Interest Expense

'

'

'

'

'

'

'

'

-507

-327

-183

Gain (loss) on derivative contracts, net

'

'

'

'

'

'

'

'

0

0

0

Other income (expense)

'

'

'

'

'

'

'

'

0

-155

0

Total other expense

'

'

'

'

'

'

'

'

-507

-482

-183

Loss from continuing operations before income tax

'

'

'

'

'

'

'

'

-590

665

-77

Income tax benefit (expense)

'

'

'

'

'

'

'

'

0

0

1,042

Income (loss) from continuing operations

'

'

'

'

'

'

'

'

-590

665

965

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

0

230

1,935

Gain (loss) on disposal of discontinued operations

'

'

'

'

'

'

'

'

0

0

0

Net income (loss)

'

'

'

'

'

'

'

'

-590

895

2,900

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-590

895

2,900

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-590

895

2,900

Total segment assets

'

23,810

'

'

17,045

'

'

'

44,193

23,810

17,045

Segment capital expenditures

'

'

'

'

'

'

'

'

22,699

8,828

6,494

Corporate Unallocated

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information

'

'

'

'

'

'

'

'

'

'

'

Oil and gas sales

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

0

0

0

Oilfield services

'

'

'

'

'

'

'

'

0

0

0

Other revenue

'

'

'

'

'

'

'

'

0

0

0

Total revenue

'

'

'

'

'

'

'

'

0

0

0

Lease operating expenses

'

'

'

'

'

'

'

'

0

0

0

Severance taxes and marketing

'

'

'

'

'

'

'

'

0

0

0

Exploration

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

0

0

0

Oilfield services

'

'

'

'

'

'

'

'

0

0

0

Impairment of proved oil and gas properties

'

'

'

'

'

'

'

'

0

0

0

Depreciation, depletion, amortization and accretion

'

'

'

'

'

'

'

'

0

0

0

Loss on sale of assets

'

'

'

'

'

'

'

'

0

0

0

General and administrative

'

'

'

'

'

'

'

'

49,241

27,137

50,794

Total expenses

'

'

'

'

'

'

'

'

49,241

27,137

50,794

OPERATING LOSS

'

'

'

'

'

'

'

'

-49,241

-27,137

-50,794

Interest income

'

'

'

'

'

'

'

'

4,824

3,483

4

Interest Expense

'

'

'

'

'

'

'

'

-67,420

-41,022

-9,879

Gain (loss) on derivative contracts, net

'

'

'

'

'

'

'

'

-7,347

13,418

-6,346

Other income (expense)

'

'

'

'

'

'

'

'

8,497

0

0

Total other expense

'

'

'

'

'

'

'

'

-61,446

-24,121

-16,221

Loss from continuing operations before income tax

'

'

'

'

'

'

'

'

-110,687

-51,258

-67,015

Income tax benefit (expense)

'

'

'

'

'

'

'

'

28,989

0

0

Income (loss) from continuing operations

'

'

'

'

'

'

'

'

-81,698

-51,258

-67,015

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

'

0

0

Gain (loss) on disposal of discontinued operations

'

'

'

'

'

'

'

'

0

0

0

Net income (loss)

'

'

'

'

'

'

'

'

-81,698

-51,258

-67,015

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

'

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-81,698

-51,258

-67,015

Dividends on preferred stock

'

'

'

'

'

'

'

'

-35,464

-22,842

-14,007

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-117,162

-74,100

-81,022

Total segment assets

'

93,612

'

'

47,839

'

'

'

77,684

93,612

47,839

Segment capital expenditures

'

'

'

'

'

'

'

'

1,037

805

9,389

Intersegment Eliminations

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information

'

'

'

'

'

'

'

'

'

'

'

Oil and gas sales

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

-8,676

-2,429

-1,484

Oilfield services

'

'

'

'

'

'

'

'

-3,117

-1,219

-2,268

Other revenue

'

'

'

'

'

'

'

'

0

2

0

Total revenue

'

'

'

'

'

'

'

'

-11,793

-3,646

-3,752

Lease operating expenses

'

'

'

'

'

'

'

'

-8,714

-3,590

-2,196

Severance taxes and marketing

'

'

'

'

'

'

'

'

0

0

0

Exploration

'

'

'

'

'

'

'

'

0

0

0

Natural gas transportation, gathering, processing, and marketing

'

'

'

'

'

'

'

'

0

120

0

Oilfield services

'

'

'

'

'

'

'

'

-3,079

-383

-1,556

Impairment of proved oil and gas properties

'

'

'

'

'

'

'

'

0

0

0

Depreciation, depletion, amortization and accretion

'

'

'

'

'

'

'

'

0

468

0

Loss on sale of assets

'

'

'

'

'

'

'

'

0

0

0

General and administrative

'

'

'

'

'

'

'

'

2,173

312

0

Total expenses

'

'

'

'

'

'

'

'

-9,620

-3,073

-3,752

OPERATING LOSS

'

'

'

'

'

'

'

'

-2,173

-573

0

Interest income

'

'

'

'

'

'

'

'

-4,823

-3,481

'

Interest Expense

'

'

'

'

'

'

'

'

7,063

3,544

2,054

Gain (loss) on derivative contracts, net

'

'

'

'

'

'

'

'

0

0

0

Other income (expense)

'

'

'

'

'

'

'

'

0

0

0

Total other expense

'

'

'

'

'

'

'

'

2,240

63

2,054

Loss from continuing operations before income tax

'

'

'

'

'

'

'

'

67

-510

2,054

Income tax benefit (expense)

'

'

'

'

'

'

'

'

0

0

-514

Income (loss) from continuing operations

'

'

'

'

'

'

'

'

67

-510

1,540

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

-69

-1,344

-1,540

Gain (loss) on disposal of discontinued operations

'

'

'

'

'

'

'

'

0

0

0

Net income (loss)

'

'

'

'

'

'

'

'

-2

-1,854

0

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

988

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

986

-1,854

0

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

986

-1,854

0

Total segment assets

'

-158,937

'

'

-127,055

'

'

'

-3,373

-158,937

-127,055

Segment capital expenditures

'

'

'

'

'

'

'

'

$0

$0

$0

[1]

The quarter-ended September 30, 2013, loss from operations was primarily driven by the loss on the sale of certain properties in Burke County, North Dakota of $38.1 million, and exploration expense. Management reviews leasehold acreage on a quarterly basis. During the quarter-ended September 30, 2013, management determined a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return.

[2]

The quarter-ended December 31, 2012, loss from operations was primarily driven by exploration expense. During the quarter-ended December 31, 2012 management determined that a significant portion of the non-core Williston Basin acreage would not be utilized as the Company planned to focus on assets that will provide a higher rate of return in 2013.

[3]

The quarter-ended September 30, 2013, loss from discontinued operations was primarily driven by impairment expense of $72.5 million, as management determined a significant portion of the non-core acreage would not be utilized.

[4]

The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".

[5]

Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.

[6]

The Companybs effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.

OTHER_INFORMATION_Details_3

OTHER INFORMATION (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Summary of costs incurred in oil and gas property acquisition, exploration, and development activities	'	'	'
Purchase of non-producing leases	$149,592	$414,037	$397,947
Purchase of producing properties	1,358	159,290	226,634
Exploration costs	11,531	165,789	112,606
Development costs	273,944	262,486	101,151
Asset retirement obligation	2,186	407	5,390
Costs incurred, acquisition of oil and gas properties, Total	$438,611	$1,002,009	$843,728

OTHER_INFORMATION_Details_4

OTHER INFORMATION (Details 4)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2009
	MBbls	MBbls	MBbls	MBbls
Crude Oil and Liquids	'	'	'	'
Summary of estimating quantities of proved reserves data	'	'	'	'
Beginning balance	45,952	21,709	'	6,824
Revisions of previous estimates	6,148	12,568	6,937	'
Purchases of reserves in place	0	10,613	6,345	'
Extensions, discoveries, and other additions	648	3,415	2,687	'
Sales of reserves in place	-15,204	-10	-215	'
Production	-2,787	-2,343	-869	'
Ending balance	34,757	45,952	21,709	6,824
Developed reserves, included above (Volume)	19,075	22,617	9,179	'
Proved undeveloped reserves (Volume)	15,682,000	23,335,000	12,531,000	'
Natural Gas	'	'	'	'
Summary of estimating quantities of proved reserves data	'	'	'	'
Beginning balance	162,620	139,237	'	39,452
Revisions of previous estimates	100,456	25,644	40,494	'
Purchases of reserves in place	88	12,082	43,757	'
Extensions, discoveries, and other additions	1,285	544	22,399	'
Sales of reserves in place	-4,185	-63	-11	'
Production	-13,482	-14,824	-6,854	'
Ending balance	246,782	162,620	139,237	39,452
Developed reserves, included above (Volume)	176,585	125,526	90,198	'
Proved undeveloped reserves (Volume)	70,197,000	37,094,000	49,039,000	'

OTHER_INFORMATION_Details_5

OTHER INFORMATION (Details 5) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Details of standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves	'	'	'
Future cash inflows	$3,711,260	$4,248,384	$2,409,249
Future production costs	-1,423,306	-1,520,260	-765,048
Future development costs	-421,797	-603,809	-330,007
Future income tax expense	-149,367	-230,500	-253,721
Future net cash flows	1,716,790	1,893,815	1,060,473
10% annual discount for estimated timing of cash flows	-872,280	-1,046,162	-586,077
Standardized measure of discounted future net cash flows	$844,510	$847,653	$474,396

OTHER_INFORMATION_Details_6

OTHER INFORMATION (Details 6) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2009
Changes in standardized measure of discounted future net cash flow relating to proved oil and gas reserves	'		'		'		'
Balance, beginning of period	$847,653		$474,396		'		$127,959
Net changes in prices and production costs	-7,355		13,647		49,498		'
Changes in estimated future development costs	-261,591		-391,318		-167,399		'
Sales and transfers of oil and gas produced during the period	-190,151		-179,384		-71,724		'
Net changes due to extensions, discoveries, and improved recovery	12,829		60,468		110,316		'
Net changes due to revisions of previous quantity estimates (1)	341,003	[1]	290,500	[1]	235,163	[1]	'
Previously estimated development costs incurred during the period	283,736		245,168		24,740		'
Accretion of discount	90,153		85,377		27,029		'
Purchase of minerals in place	218		217,791		234,336		'
Sale of minerals in place	-236,885		-354		-3,726		'
Changes in timing and other (2)	-91,088	[2]	22,436	[2]	824	[2]	'
Net change in income taxes	55,988		8,926		-92,620		'
Standardized measure of discounted future net cash flows	$844,510		$847,653		$474,396		$127,959
Crude Oil and Liquids	'		'		'		'
Changes in standardized measure of discounted future net cash flow relating to proved oil and gas reserves	'		'		'		'
Revisions of previous estimates (volume)	6,148		12,568		6,937		'
Natural Gas	'		'		'		'
Changes in standardized measure of discounted future net cash flow relating to proved oil and gas reserves	'		'		'		'
Revisions of previous estimates (volume)	100,456		25,644		40,494		'
[1]	The Company's net changes due to revisions of previous quantity estimates primarily reflect upward revisions to recoverable quantities of oil and gas minerals assuming existing prices and technology. For the year ended December 31, 2013, the Company made upward revisions of 6,148 MBbl of oil and natural gas liquids and 100,456 MMcf of natural gas due to additional information gathered from continued production from the shale areas and increases in estimated ultimate recoveries (EURs). For the year ended December 31, 2012, the Company made upward revisions of 12,568 MBbls of oil and natural gas liquids and 25,644 MMcf of natural gas.
[2]	The Company's changes in timing and other primarily represent changes in the Company's estimates of when proved reserve quantities will be realized. The reserves as of December 31, 2012, reflect accelerated recovery of minerals due to purchases of minerals in place and capital expenditures incurred to develop properties.

OTHER_INFORMATION_Details_7

OTHER INFORMATION (Details 7)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Oil (per bbl)	'	'	'
Average Sales Price and Production Costs Per Unit of Production	'	'	'
Commodity prices inclusive of adjustments for quality and location	93.13	88.37	96.19
Natural gas liquids (per bbl)	'	'	'
Average Sales Price and Production Costs Per Unit of Production	'	'	'
Commodity prices inclusive of adjustments for quality and location	43.79	53.94	44.25
Gas (per mcf)	'	'	'
Average Sales Price and Production Costs Per Unit of Production	'	'	'
Commodity prices inclusive of adjustments for quality and location	4.14	3.08	4.11

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	0 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Feb. 17, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Pilatus Hunter	'	'		'		'
Related Party Transaction	'	'		'		'
Percentage of ownership in related party by member of management	'	100.00%		100.00%		100.00%
Pilatus Hunter | Airplane rental expenses	'	'		'		'
Related Party Transaction	'	'		'		'
Related party expenses	'	$166	[1]	$174	[1]	$463	[1]
GreenHunter Resources, Inc. [Member]	'	'		'		'
Related Party Transaction	'	'		'		'
Accounts receivable - net	'	23	[2]	0	[2]	'
Derivative assets	'	79		264		'
Investments	'	2,262	[2],[3]	3,009	[2],[3]	'
Notes receivable (2)	'	1,768	[2]	2,173	[2]	'
Prepaid expenses	'	9	[2]	0	[2]	'
Interest Income from Note Receivable	'	205	[3]	191	[3]	0	[3]
Loss on investments	'	730	[3]	1,333	[3]	0	[3]
Related Party Transaction Rental Agreement Term	'5 years	'		'		'
GreenHunter Resources, Inc. [Member] | Rental expenses	'	'		'		'
Related Party Transaction	'	'		'		'
Related party expenses	'	282	[2]	1,000	[2]	1	[2]
GreenHunter Resources, Inc. [Member] | Office space rental	'	'		'		'
Related Party Transaction	'	'		'		'
Related party expenses	'	13	[2]	0	[2]	0	[2]
GreenHunter Resources, Inc. [Member] | Professional services	'	'		'		'
Related Party Transaction	'	'		'		'
Related party expenses	'	0	[2]	0	[2]	162	[2]
GreenHunter Resources, Inc. [Member] | Water disposal charges	'	'		'		'
Related Party Transaction	'	'		'		'
Related party expenses	'	3,033	[2]	2,400	[2]	0	[2]
Executive Officer | Corporate apartment rental	'	'		'		'
Related Party Transaction	'	'		'		'
Related party expenses	'	0	[4]	23	[4]	36	[4]
Series C Preferred Stock | GreenHunter Resources, Inc. [Member]	'	'		'		'
Related Party Transaction	'	'		'		'
Dividends received from Series C shares	'	$220		$0		$0
[1]	The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense.
[2]	GreenHunter is an entity of which Gary C. Evans, Magnum Hunter's Chairman and CEO, is the Chairman, a major shareholder and former interim CEO; of which David Krueger, the Company's former Chief Accounting Officer and Senior Vice President, is the former Chief Financial Officer; and of which Ronald D. Ormand, the Companybs former Chief Financial Officer and Executive Vice President, is a former director. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources, Inc. ("Virco"), 100% owned subsidiaries of the Company, receive services related to salt water disposal and rental equipment from GreenHunter and its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services.
[3]	On February 17, 2012, the Company sold its 100% owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a 100% owned subsidiary of GreenHunter. The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. The Company has recorded interest income at the rate of 10% on the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and other long term assets and an available for sale investment in GreenHunter included in investments.
[4]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOjVjOGRjMjk4MmU1MjQ4YWZhNDYxOTViYTk1OTFhMDVhfFRleHRTZWxlY3Rpb246MTIyREVCMERBNDZBNDU3MkQ0REU0OTFBQjRCQUI0NUIM}

RELATED_PARTY_TRANSACTIONS_Det1

RELATED PARTY TRANSACTIONS (Details 2) (USD $)

0 Months Ended

3 Months Ended

12 Months Ended

Feb. 17, 2012

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Related Party Transaction

'

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of promissory notes convertible into GreenHunter Energy, Inc common stock (in shares)

880,000

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of promissory notes convertible into GreenHunter Energy, Inc common stock, conversion price (in dollars per share)

$2.50

'

'

'

'

'

'

'

'

'

'

'

Gain on disposal of discontinued operations, net of tax

'

$0

[1]

($35,979,000)

[1]

($84,454,000)

[1]

$172,452,000

[1]

$185,000

$0

($2,101,000)

$4,325,000

$52,019,000

[1],[2],[3]

$2,409,000

[2],[3]

$0

[2],[3]

Adjusted cash proceeds for changes in working capital to reflect the effective date of the sale

'

'

'

'

'

'

'

'

'

'

783,000

'

GreenHunter Resources, Inc. [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction

'

'

'

'

'

'

'

'

'

'

'

'

Total consideration received

9,300,000

'

'

'

'

'

'

'

'

'

'

'

Cash consideration received

2,200,000

'

'

'

'

'

'

'

'

'

'

'

Consideration received, number of shares of common stock received

1,846,722

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of common stock received

2,600,000

'

'

'

'

'

'

'

'

'

'

'

Common stock issued (in dollars per share)

$1.79

'

'

'

'

'

'

'

'

'

'

'

Consideration received, number of shares of preferred stock received

88,000

'

'

'

'

'

'

'

'

'

'

'

Consideration received, cumulative preferred dividend rate on preferred stock received (as a percent)

10.00%

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of preferred stock received

1,900,000

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of promissory notes convertible into GreenHunter Energy, Inc common stock

2,200,000

'

'

'

'

'

'

'

'

'

'

'

Derivative assets

'

'

264,000

'

'

'

'

'

'

79,000

264,000

'

Interest income

'

'

'

'

'

'

'

'

'

205,000

[4]

191,000

[4]

0

[4]

Loss on investments

'

'

'

'

'

'

'

'

'

730,000

[4]

1,333,000

[4]

0

[4]

Tank rental agreement term

'5 years

'

'

'

'

'

'

'

'

'

'

'

Level 3 | Convertible security derivative assets

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued (in dollars per share)

'

'

'

'

'

'

'

'

'

$1.18

'

'

Level 3 | Convertible security derivative assets | Recurring [Member] | GreenHunter Resources, Inc. [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction

'

'

'

'

'

'

'

'

'

'

'

'

Derivative assets

'

'

$264,000

[5]

'

'

'

'

'

'

$79,000

[5]

$264,000

[5]

'

[1]

The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".

[2]

Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.

[3]

The Companybs effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.

[4]

On February 17, 2012, the Company sold its 100% owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a 100% owned subsidiary of GreenHunter. The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. The Company has recorded interest income at the rate of 10% on the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and other long term assets and an available for sale investment in GreenHunter included in investments.

[5]

GreenHunter is an entity of which Gary C. Evans, Magnum Hunter's Chairman and CEO, is the Chairman, a major shareholder and former interim CEO; of which David Krueger, the Company's former Chief Accounting Officer and Senior Vice President, is the former Chief Financial Officer; and of which Ronald D. Ormand, the Companybs former Chief Financial Officer and Executive Vice President, is a former director. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources, Inc. ("Virco"), 100% owned subsidiaries of the Company, receive services related to salt water disposal and rental equipment from GreenHunter and its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services.

RELATED_PARTY_TRANSACTIONS_Det2

RELATED PARTY TRANSACTIONS (Details 3) (USD $)	0 Months Ended
In Thousands, except Share data, unless otherwise specified	Apr. 02, 2012
Mr. Evans	'
RELATED PARTY TRANSACTIONS	'
Percentage of ownership	4.00%
Mr. Evans | Eureka Hunter Holdings, LLC | Class A Common Units	'
RELATED PARTY TRANSACTIONS	'
Common units acquired (in shares)	27,641
Purchase price of common units acquired	553
Trans Tex Gas Services | Eureka Hunter Holdings, LLC	'
RELATED PARTY TRANSACTIONS	'
Common units acquired (in shares)	622,641
Cash	46,047
Trans Tex Gas Services | Eureka Hunter Holdings, LLC | Class A Common Units	'
RELATED PARTY TRANSACTIONS	'
Common units acquired (in shares)	622,641
Cash	46,000

COMMITMENTS_AND_CONTINGENCIES_1

COMMITMENTS AND CONTINGENCIES (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2013

Sep. 26, 2008

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jun. 27, 2012

Dec. 14, 2011

Dec. 31, 2013

Dec. 14, 2011

Dec. 31, 2013

Dec. 31, 2013

Apr. 24, 2013

Aug. 12, 2013

Dec. 17, 2013

Oct. 31, 2013

Oct. 07, 2013

Dec. 31, 2012

Dec. 31, 2011

Drilling Rig Purchase Commitment

Ridgeline

Partnership Interest Purchase Agreement Commitments

Partnership Interest Purchase Agreement Commitments

Lease Commitments

Lease Commitments

Lease Commitments

Lease Commitments

Gathering, processing, and transportation commitments

Gathering, processing, and transportation commitments

Gathering, processing, and transportation commitments

Gathering, processing, and transportation commitments

Gathering, processing, and transportation commitments

Gathering, processing, and transportation commitments

Class action complaint filed by Horace Carvalho

Utica Shale Assets Acquisition

Utica Shale Assets Acquisition

Utica Shale Assets Acquisition

Utica Shale Assets Acquisition

Common Stock

Common Stock

Hall-Houston Exploration II, L. P.

Hall-Houston Exploration II, L. P.

Houston, Texas

Triad Hunter

Triad Hunter

Williston Hunter

Triad Hunter

Triad Hunter

Eureka Hunter Pipelines, LLC

Subsequent event

acre

acre

acre

acre

Maximum

Calgary, Alberta and Denver, Colorado

officer

Commitments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of the Company's officers subject to class action complaint

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

Stock issued (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35,000,000

1,714,000

Net mineral acres acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

32,000

'

'

'

'

'

Period over which acquisition takes place

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 months

'

'

'

'

'

Recognized identifiable assets acquired and liabilities assumed, land

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$10,900,000

$8,700,000

$4,900,000

'

'

Net leasehold acres purchased

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,837.64

2,050.40

1,156.14

'

'

Percentage sales of partnership interest purchase agreement

'

'

5.33%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partnership interest sale cash consideration

'

'

8,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

First call

'

'

1,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partnership interest sale reimbursement for first capital call

'

'

754,255

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Remaining maximum liability

'

'

'

640,695

'

'

'

'

'

'

3,200,000

'

3,500,000

21,900,000

'

'

'

'

'

'

'

Term of commitment

'

'

'

'

'

'

'12 months

'

'36 months

'120 months

'

'120 months

'

'

'

'

'

'

'

'

'

Lease cost

'

'

'

'

33,000

4,800

'

5,800

'

'

'

'

'

'

'

'

'

'

'

'

'

Remaining commitment under agreement

$15,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of equity ownership Ridgeline has the right to purchase upon change of control

'

51.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

COMMITMENTS_AND_CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES (Details 2) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Future minimum base rentals of Transtex Hunter's non-cancelable leases	'
2014	$504
2015	457
2016	239
2016	121
2017	127
Thereafter	$53

COMMITMENTS_AND_CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES (Details 3) (Gathering, processing, and transportation commitments, USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Gathering, processing, and transportation commitments	'
Other Commitments [Line Items]	'
2014	$4,332
2015	4,319
2016	3,373
2017	2,958
2018	2,947
Thereafter	$10,722

CONDENSED_CONSOLIDATING_GUARAN2

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified
CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	'	'	'	'
Percent ownership of subsidiaries	100.00%	'	'	'
ASSETS	'	'	'	'
Current assets	$120,726	$204,319	'	'
Property and equipment (using successful efforts accounting)	1,514,079	1,924,413	'	'
Total assets	1,856,651	2,198,632	1,168,760	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	183,865	243,656	'	'
Redeemable preferred stock	236,675	200,878	'	'
Shareholders' equity	450,730	711,652	490,652	103,322
Total liabilities and shareholdersb equity	1,856,651	2,198,632	'	'
Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
ASSETS	'	'	'	'
Current assets	120,726	204,319	'	'
Intercompany accounts receivable	0	0	'	'
Property and equipment (using successful efforts accounting)	1,514,079	1,924,413	'	'
Investment in subsidiaries	0	0	'	'
Other assets	221,846	69,900	'	'
Total assets	1,856,651	2,198,632	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	183,865	243,656	'	'
Intercompany accounts payable	0	0	'	'
Long-term liabilities	985,381	1,042,446	'	'
Redeemable preferred stock	236,675	200,878	'	'
Shareholders' equity	450,730	711,652	'	'
Total liabilities and shareholdersb equity	1,856,651	2,198,632	'	'
Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
ASSETS	'	'	'	'
Current assets	120,726	204,319	'	'
Intercompany accounts receivable	0	0	'	'
Property and equipment (using successful efforts accounting)	1,514,079	1,924,413	'	'
Investment in subsidiaries	0	0	'	'
Other assets	221,846	69,900	'	'
Total assets	1,856,651	2,198,632	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	183,865	243,656	'	'
Intercompany accounts payable	0	0	'	'
Long-term liabilities	985,381	1,042,446	'	'
Redeemable preferred stock	236,675	200,878	'	'
Shareholders' equity	450,730	711,652	'	'
Total liabilities and shareholdersb equity	1,856,651	2,198,632	'	'
Magnum Hunter Resources Corporation | Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
ASSETS	'	'	'	'
Current assets	53,161	63,167	'	'
Intercompany accounts receivable	965,138	803,834	'	'
Property and equipment (using successful efforts accounting)	7,214	9,596	'	'
Investment in subsidiaries	372,236	763,856	'	'
Other assets	17,308	20,849	'	'
Total assets	1,415,057	1,661,302	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	54,826	28,503	'	'
Intercompany accounts payable	0	0	'	'
Long-term liabilities	818,651	831,286	'	'
Redeemable preferred stock	100,000	100,000	'	'
Shareholders' equity	441,580	701,513	'	'
Total liabilities and shareholdersb equity	1,415,057	1,661,302	'	'
Magnum Hunter Resources Corporation | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
ASSETS	'	'	'	'
Current assets	53,161	63,167	'	'
Intercompany accounts receivable	965,138	803,834	'	'
Property and equipment (using successful efforts accounting)	7,214	9,596	'	'
Investment in subsidiaries	372,236	763,856	'	'
Other assets	17,308	20,849	'	'
Total assets	1,415,057	1,661,302	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	54,826	28,503	'	'
Intercompany accounts payable	0	0	'	'
Long-term liabilities	818,651	831,286	'	'
Redeemable preferred stock	100,000	100,000	'	'
Shareholders' equity	441,580	701,513	'	'
Total liabilities and shareholdersb equity	1,415,057	1,661,302	'	'
PRC Williston, Inc. | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
ASSETS	'	'	'	'
Current assets	6,013	703	'	'
Intercompany accounts receivable	0	0	'	'
Property and equipment (using successful efforts accounting)	0	18,257	'	'
Investment in subsidiaries	0	0	'	'
Other assets	0	0	'	'
Total assets	6,013	18,960	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	2,035	2,291	'	'
Intercompany accounts payable	45,661	58,966	'	'
Long-term liabilities	0	1,274	'	'
Redeemable preferred stock	0	0	'	'
Shareholders' equity	-41,683	-43,571	'	'
Total liabilities and shareholdersb equity	6,013	18,960	'	'
Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
ASSETS	'	'	'	'
Current assets	28,825	48,320	'	'
Intercompany accounts receivable	0	0	'	'
Property and equipment (using successful efforts accounting)	1,124,637	1,148,714	'	'
Investment in subsidiaries	102,314	101,342	'	'
Other assets	100,327	5,341	'	'
Total assets	1,356,103	1,303,717	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	86,115	109,536	'	'
Intercompany accounts payable	896,242	611,932	'	'
Long-term liabilities	23,115	83,192	'	'
Redeemable preferred stock	0	0	'	'
Shareholders' equity	350,631	499,057	'	'
Total liabilities and shareholdersb equity	1,356,103	1,303,717	'	'
Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
ASSETS	'	'	'	'
Current assets	43,841	60,552	'	'
Intercompany accounts receivable	0	0	'	'
Property and equipment (using successful efforts accounting)	1,272,027	1,276,467	'	'
Investment in subsidiaries	102,314	101,341	'	'
Other assets	100,894	5,451	'	'
Total assets	1,519,076	1,443,811	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	97,520	117,511	'	'
Intercompany accounts payable	921,237	508,254	'	'
Long-term liabilities	39,067	97,271	'	'
Redeemable preferred stock	0	0	'	'
Shareholders' equity	461,252	720,775	'	'
Total liabilities and shareholdersb equity	1,519,076	1,443,811	'	'
Non Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
ASSETS	'	'	'	'
Current assets	42,112	124,041	'	'
Intercompany accounts receivable	0	0	'	'
Property and equipment (using successful efforts accounting)	382,228	766,103	'	'
Investment in subsidiaries	0	102,354	'	'
Other assets	104,211	43,710	'	'
Total assets	528,551	1,036,208	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	46,334	135,994	'	'
Intercompany accounts payable	68,861	191,902	'	'
Long-term liabilities	143,615	127,968	'	'
Redeemable preferred stock	136,675	100,878	'	'
Shareholders' equity	133,066	479,466	'	'
Total liabilities and shareholdersb equity	528,551	1,036,208	'	'
Non Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
ASSETS	'	'	'	'
Current assets	21,083	111,126	'	'
Intercompany accounts receivable	0	0	'	'
Property and equipment (using successful efforts accounting)	234,838	620,093	'	'
Investment in subsidiaries	0	102,354	'	'
Other assets	103,644	43,600	'	'
Total assets	359,565	877,173	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	32,894	125,727	'	'
Intercompany accounts payable	-1,795	236,636	'	'
Long-term liabilities	127,663	112,615	'	'
Redeemable preferred stock	136,675	100,878	'	'
Shareholders' equity	64,128	301,317	'	'
Total liabilities and shareholdersb equity	359,565	877,173	'	'
Eliminations | Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
ASSETS	'	'	'	'
Current assets	-3,372	-31,209	'	'
Intercompany accounts receivable	-965,138	-803,834	'	'
Property and equipment (using successful efforts accounting)	0	0	'	'
Investment in subsidiaries	-474,550	-967,552	'	'
Other assets	0	0	'	'
Total assets	-1,443,060	-1,802,595	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	-3,410	-30,377	'	'
Intercompany accounts payable	-965,103	-803,834	'	'
Long-term liabilities	0	0	'	'
Redeemable preferred stock	0	0	'	'
Shareholders' equity	-474,547	-968,384	'	'
Total liabilities and shareholdersb equity	-1,443,060	-1,802,595	'	'
Eliminations | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
ASSETS	'	'	'	'
Current assets	-3,372	-31,229	'	'
Intercompany accounts receivable	-965,138	-803,834	'	'
Property and equipment (using successful efforts accounting)	0	0	'	'
Investment in subsidiaries	-474,550	-967,551	'	'
Other assets	0	0	'	'
Total assets	-1,443,060	-1,802,614	'	'
LIABILITIES AND SHAREHOLDERS' EQUITY	'	'	'	'
Current liabilities	-3,410	-30,376	'	'
Intercompany accounts payable	-965,103	-803,856	'	'
Long-term liabilities	0	0	'	'
Redeemable preferred stock	0	0	'	'
Shareholders' equity	-474,547	-968,382	'	'
Total liabilities and shareholdersb equity	($1,443,060)	($1,802,614)	'	'

CONDENSED_CONSOLIDATING_GUARAN3

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 2) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2011

Sep. 30, 2011

Jun. 30, 2011

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

$54,235

$85,237

$73,032

$67,907

$45,432

$36,381

$30,598

$27,945

$280,411

$140,356

$66,455

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-274,349

-138,968

-59,676

Income tax benefit (expense)

'

'

'

'

'

'

'

'

70,297

19,312

2,862

Loss from continuing operations

-61,544

-10,257

-132,598

347

-57,172

-31,313

-8,638

-22,533

-204,052

-119,656

-56,814

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

-19,112

-17,065

-19,598

Gain on disposal of discontinued operations, net of tax

0

[1]

-35,979

[1]

-84,454

[1]

172,452

[1]

185

0

-2,101

4,325

52,019

[1],[2],[3]

2,409

[2],[3]

0

[2],[3]

Net income (loss)

'

'

'

'

'

'

'

'

-223,164

-136,721

-76,412

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

988

4,013

-249

Net loss attributable to Magnum Hunter Resources Corporation

-44,197

-46,537

-296,882

165,440

-75,210

-32,463

-12,577

-12,458

-222,176

-132,708

-76,661

Dividends on preferred stock

'

'

'

'

'

'

'

'

-56,705

-34,706

-14,007

Net loss attributable to common shareholders

-57,685

-61,208

-311,299

151,311

-87,236

-42,283

-20,843

-17,052

-278,881

-167,414

-90,668

Debt Securities Under Universal Shelf Registration Statement Form S-3

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

280,411

140,356

66,455

Expenses

'

'

'

'

'

'

'

'

554,760

279,324

126,131

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-274,349

-138,968

-59,676

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

0

0

0

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-274,349

-138,968

-59,676

Income tax benefit (expense)

'

'

'

'

'

'

'

'

70,297

19,312

2,862

Loss from continuing operations

'

'

'

'

'

'

'

'

-204,052

-119,656

-56,814

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

-71,131

-19,474

-19,598

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

52,019

2,409

0

Net income (loss)

'

'

'

'

'

'

'

'

-223,164

-136,721

-76,412

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

988

4,013

-249

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-222,176

-132,708

-76,661

Dividends on preferred stock

'

'

'

'

'

'

'

'

-56,705

-34,706

-14,007

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-278,881

-167,414

-90,668

Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

280,411

140,356

66,455

Expenses

'

'

'

'

'

'

'

'

554,760

279,324

126,131

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-274,349

-138,968

-59,676

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

0

0

0

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-274,349

-138,968

-59,676

Income tax benefit (expense)

'

'

'

'

'

'

'

'

70,297

19,312

2,862

Loss from continuing operations

'

'

'

'

'

'

'

'

-204,052

-119,656

-56,814

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

-71,131

-19,474

-19,598

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

52,019

2,409

0

Net income (loss)

'

'

'

'

'

'

'

'

-223,164

-136,721

-76,412

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

988

4,013

-249

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-222,176

-132,708

-76,661

Dividends on preferred stock

'

'

'

'

'

'

'

'

-56,705

-34,706

-14,007

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-278,881

-167,414

-90,668

Magnum Hunter Resources Corporation | Debt Securities Under Universal Shelf Registration Statement Form S-3

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

2,629

729

1,071

Expenses

'

'

'

'

'

'

'

'

112,754

54,047

68,772

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-110,125

-53,318

-67,701

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-298,775

-97,191

-5,208

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-408,900

-150,509

-72,909

Income tax benefit (expense)

'

'

'

'

'

'

'

'

28,989

5,937

0

Loss from continuing operations

'

'

'

'

'

'

'

'

-379,911

-144,572

-72,909

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

-7,813

0

0

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

144,378

0

0

Net income (loss)

'

'

'

'

'

'

'

'

-243,346

-144,572

-72,909

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-243,346

-144,572

-72,909

Dividends on preferred stock

'

'

'

'

'

'

'

'

-35,464

-22,842

-14,007

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-278,810

-167,414

-86,916

Magnum Hunter Resources Corporation | Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

2,629

729

1,071

Expenses

'

'

'

'

'

'

'

'

112,754

54,047

68,772

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-110,125

-53,318

-67,701

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-298,775

-97,191

-6,906

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-408,900

-150,509

-74,607

Income tax benefit (expense)

'

'

'

'

'

'

'

'

28,989

5,937

0

Loss from continuing operations

'

'

'

'

'

'

'

'

-379,911

-144,572

-74,607

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

-7,813

0

0

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

144,378

0

0

Net income (loss)

'

'

'

'

'

'

'

'

-243,346

-144,572

-74,607

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-243,346

-144,572

-74,607

Dividends on preferred stock

'

'

'

'

'

'

'

'

-35,464

-22,842

-14,007

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-278,810

-167,414

-88,614

PRC Williston, Inc. | Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

0

0

0

Expenses

'

'

'

'

'

'

'

'

3,583

3,289

4,715

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-3,583

-3,289

-4,715

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

0

0

0

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-3,583

-3,289

-4,715

Income tax benefit (expense)

'

'

'

'

'

'

'

'

0

0

0

Loss from continuing operations

'

'

'

'

'

'

'

'

-3,583

-3,289

-4,715

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

-1,674

-11,602

1,698

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

7,145

0

0

Net income (loss)

'

'

'

'

'

'

'

'

1,888

-14,891

-3,017

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

1,888

-14,891

-3,017

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

1,888

-14,891

-3,017

Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-3

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

187,095

103,605

45,119

Expenses

'

'

'

'

'

'

'

'

326,355

159,603

39,226

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-139,260

-55,998

5,893

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-424

458

-2,196

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-139,684

-55,540

3,697

Income tax benefit (expense)

'

'

'

'

'

'

'

'

41,315

13,375

-3,727

Loss from continuing operations

'

'

'

'

'

'

'

'

-98,369

-42,165

7,424

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

13,101

-11,036

-30,374

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

-18,507

2,409

0

Net income (loss)

'

'

'

'

'

'

'

'

-103,775

-50,792

-22,950

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-103,775

-50,792

-22,950

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-103,775

-50,792

-22,950

Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

254,209

122,703

54,545

Expenses

'

'

'

'

'

'

'

'

394,328

177,489

48,788

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-140,119

-54,786

5,757

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-424

458

-2,196

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-140,543

-54,328

3,561

Income tax benefit (expense)

'

'

'

'

'

'

'

'

41,305

13,375

-3,733

Loss from continuing operations

'

'

'

'

'

'

'

'

-99,238

-40,953

7,294

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

13,085

-11,056

-30,364

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

-18,507

2,409

0

Net income (loss)

'

'

'

'

'

'

'

'

-104,660

-49,600

-23,070

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-104,660

-49,600

-23,070

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-104,660

-49,600

-23,070

Non Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-3

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

95,286

[4]

32,054

[4]

15,329

[4]

Expenses

'

'

'

'

'

'

'

'

125,786

[4]

49,597

[4]

16,949

[4]

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-30,500

[4]

-17,543

[4]

-1,620

[4]

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

0

[4]

-23,362

[4]

-939

[4]

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-30,500

[4]

-40,905

[4]

-2,559

[4]

Income tax benefit (expense)

'

'

'

'

'

'

'

'

-7

[4]

0

[4]

-351

[4]

Loss from continuing operations

'

'

'

'

'

'

'

'

-30,507

[4]

-40,905

[4]

-2,910

[4]

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

-78,025

[4]

-18,695

[4]

14,014

[4]

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

-66,707

[4]

0

[4]

0

[4]

Net income (loss)

'

'

'

'

'

'

'

'

-175,239

[4]

-59,600

[4]

11,104

[4]

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

[4]

0

[4]

0

[4]

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-175,239

[4]

-59,600

[4]

11,104

[4]

Dividends on preferred stock

'

'

'

'

'

'

'

'

-21,241

[4]

-11,864

[4]

0

[4]

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-196,480

[4]

-71,464

[4]

11,104

[4]

Non Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

28,172

12,955

5,903

Expenses

'

'

'

'

'

'

'

'

54,231

9,929

7,677

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

-26,059

3,026

-1,774

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

0

-23,362

-939

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

-26,059

-20,336

-2,713

Income tax benefit (expense)

'

'

'

'

'

'

'

'

3

'

-357

Loss from continuing operations

'

'

'

'

'

'

'

'

-26,056

-20,336

-3,070

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

-76,335

-8,418

12,306

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

-73,852

0

0

Net income (loss)

'

'

'

'

'

'

'

'

-176,243

-28,754

9,236

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

-176,243

-28,754

9,236

Dividends on preferred stock

'

'

'

'

'

'

'

'

-21,241

-11,864

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

-197,484

-40,618

9,236

Eliminations | Debt Securities Under Universal Shelf Registration Statement Form S-3

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

-4,599

[4]

3,968

[4]

4,936

[4]

Expenses

'

'

'

'

'

'

'

'

-10,135

[4]

16,077

[4]

1,184

[4]

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

5,536

[4]

-12,109

[4]

3,752

[4]

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

299,199

[4]

120,095

[4]

8,343

[4]

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

304,735

[4]

107,986

[4]

12,095

[4]

Income tax benefit (expense)

'

'

'

'

'

'

'

'

0

[4]

0

[4]

514

[4]

Loss from continuing operations

'

'

'

'

'

'

'

'

304,735

[4]

107,986

[4]

11,581

[4]

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

1,606

[4]

10,257

[4]

-3,238

[4]

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

-7,145

[4]

0

[4]

0

[4]

Net income (loss)

'

'

'

'

'

'

'

'

299,196

[4]

118,243

[4]

8,343

[4]

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

988

[4]

4,013

[4]

-249

[4]

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

300,184

[4]

122,256

[4]

8,094

[4]

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

[4]

0

[4]

0

[4]

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

300,184

[4]

122,256

[4]

8,094

[4]

Eliminations | Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

-4,599

3,969

4,936

Expenses

'

'

'

'

'

'

'

'

-10,136

34,570

-3,821

Loss from continuing operations before equity in net income of subsidiaries

'

'

'

'

'

'

'

'

5,537

-30,601

8,757

Equity in net income of subsidiaries

'

'

'

'

'

'

'

'

299,199

120,095

10,041

LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX

'

'

'

'

'

'

'

'

304,736

89,494

18,798

Income tax benefit (expense)

'

'

'

'

'

'

'

'

0

0

514

Loss from continuing operations

'

'

'

'

'

'

'

'

304,736

89,494

18,284

Income from discontinued operations, net of taxes

'

'

'

'

'

'

'

'

1,606

11,602

-3,238

Gain on disposal of discontinued operations, net of tax

'

'

'

'

'

'

'

'

-7,145

0

0

Net income (loss)

'

'

'

'

'

'

'

'

299,197

101,096

15,046

Net loss (income) attributable to non-controlling interest

'

'

'

'

'

'

'

'

988

4,013

-249

Net loss attributable to Magnum Hunter Resources Corporation

'

'

'

'

'

'

'

'

300,185

105,109

14,797

Dividends on preferred stock

'

'

'

'

'

'

'

'

0

0

0

Net loss attributable to common shareholders

'

'

'

'

'

'

'

'

300,185

105,109

14,797

Magnum Hunter Resources Corporation Consolidated | Debt Securities Under Universal Shelf Registration Statement Form S-3

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

'

'

-223,164

-136,721

-76,412

Magnum Hunter Resources Corporation Consolidated | Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

'

'

-223,164

-136,721

-76,412

PRC Williston Inc | Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

'

'

1,888

-14,891

-3,017

Wholly-Owned Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-4

'

'

'

'

'

'

'

'

'

'

'

Condensed consolidating statements of operations

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

'

'

($104,660)

($49,600)

($23,070)

[1]

The quarter-ended June 30, 2013 gain on disposal of discontinued operations was primarily due to the gain on sale of the Company's Eagle Ford Shale assets. The quarter-ended September 30, 2013 loss on disposal of discontinued operations was primarily due to an expense of $64.8 million, net of tax to reflect the net assets of Magnum Hunter Production and Williston Hunter Canada to their fair values as a result of the Company's decision to sell these assets. The quarter-ended December 31, 2013 loss on disposal of discontinued operations was primarily due to an expense of $27.6 million, net of tax, to reflect changes in the estimated fair values of the net assets of Magnum Hunter Production and Williston Hunter Canada which the Company had decided to sell during the quarter ended September 30, 2013. See "Note 2 - Divestitures and Discontinued Operations".

[2]

Income tax expense associated with gain/(loss) on sale of discontinued operations was $1.4 million, $1.3 million, and none for the years ended December 31, 2013, 2012, and 2011, respectively.

[3]

The Companybs effective tax rate on the gain on disposal of discontinued operations is 2.6% primarily due to the anticipated utilization of a capital loss on the sale of WHI Canada against the capital gains included in discontinued operations.

[4]

PRC Williston, LLC has been presented as a discontinued operation on a stand alone basis. Elimination entries have been recorded to eliminate discontinued operations treatment on a consolidated basis.

CONDENSED_CONSOLIDATING_GUARAN4

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Net income (loss)	($223,164)		($136,721)		($76,412)
Foreign currency translation gain (loss)	-10,928		3,883		-12,477
Unrealized gain (loss) on available for sale investments	-84	[1]	-309	[1]	'
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	-8,262		0		0
Comprehensive loss	-234,176		-133,147		-88,875
Comprehensive (income) loss attributable to non-controlling interests	988		4,013		-249
Comprehensive loss attributable to Magnum Hunter Resources Corporation	-233,188		-129,134		-89,124
Debt Securities Under Universal Shelf Registration Statement Form S-3	'		'		'
Net income (loss)	-223,164		-136,721		-76,412
Debt Securities Under Universal Shelf Registration Statement Form S-3 | Magnum Hunter Resources Corporation	'		'		'
Net income (loss)	-243,346		-144,572		-72,909
Foreign currency translation gain (loss)	0		0		0
Unrealized gain (loss) on available for sale investments	8,262		0		0
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	-8,262		'		'
Comprehensive loss	-243,346		-144,572		-72,909
Comprehensive (income) loss attributable to non-controlling interests	0		0		0
Comprehensive loss attributable to Magnum Hunter Resources Corporation	-243,346		-144,572		-72,909
Debt Securities Under Universal Shelf Registration Statement Form S-3 | Guarantor Subsidiaries	'		'		'
Net income (loss)	-103,775		-50,792		-22,950
Foreign currency translation gain (loss)	0		0		0
Unrealized gain (loss) on available for sale investments	-84		-309		14
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	0		'		'
Comprehensive loss	-103,859		-51,101		-22,936
Comprehensive (income) loss attributable to non-controlling interests	0		0		0
Comprehensive loss attributable to Magnum Hunter Resources Corporation	-103,859		-51,101		-22,936
Debt Securities Under Universal Shelf Registration Statement Form S-3 | Non Guarantor Subsidiaries	'		'		'
Net income (loss)	-175,239	[2]	-59,600	[2]	11,104	[2]
Foreign currency translation gain (loss)	-10,928		3,883		-12,477
Unrealized gain (loss) on available for sale investments	0		0		0
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	0		'		'
Comprehensive loss	-186,167		-55,717		-1,373
Comprehensive (income) loss attributable to non-controlling interests	0		0		0
Comprehensive loss attributable to Magnum Hunter Resources Corporation	-186,167		-55,717		-1,373
Debt Securities Under Universal Shelf Registration Statement Form S-3 | Eliminations	'		'		'
Net income (loss)	299,196	[2]	118,243	[2]	8,343	[2]
Foreign currency translation gain (loss)	0		0		0
Unrealized gain (loss) on available for sale investments	0		0		0
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	0		'		'
Comprehensive loss	299,196		118,243		8,343
Comprehensive (income) loss attributable to non-controlling interests	988		4,013		-249
Comprehensive loss attributable to Magnum Hunter Resources Corporation	300,184		122,256		8,094
Debt Securities Under Universal Shelf Registration Statement Form S-3 | Magnum Hunter Resources Corporation Consolidated	'		'		'
Net income (loss)	-223,164		-136,721		-76,412
Foreign currency translation gain (loss)	-10,928		3,883		-12,477
Unrealized gain (loss) on available for sale investments	8,178		-309		14
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	-8,262		'		'
Comprehensive loss	-234,176		-133,147		-88,875
Comprehensive (income) loss attributable to non-controlling interests	988		4,013		-249
Comprehensive loss attributable to Magnum Hunter Resources Corporation	-233,188		-129,134		-89,124
Debt Securities Under Universal Shelf Registration Statement Form S-4	'		'		'
Net income (loss)	-223,164		-136,721		-76,412
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'		'		'
Net income (loss)	-243,346		-144,572		-74,607
Foreign currency translation gain (loss)	0		0		0
Unrealized gain (loss) on available for sale investments	8,262		0		0
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	-8,262		'		'
Comprehensive loss	-243,346		-144,572		-74,607
Comprehensive (income) loss attributable to non-controlling interests	0		0		0
Comprehensive loss attributable to Magnum Hunter Resources Corporation	-243,346		-144,572		-74,607
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Guarantor Subsidiaries	'		'		'
Net income (loss)	-104,660		-49,600		-23,070
Debt Securities Under Universal Shelf Registration Statement Form S-4 | PRC Williston Inc	'		'		'
Net income (loss)	1,888		-14,891		-3,017
Foreign currency translation gain (loss)	0		0		0
Unrealized gain (loss) on available for sale investments	0		0		0
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	0		'		'
Comprehensive loss	1,888		-14,891		-3,017
Comprehensive (income) loss attributable to non-controlling interests	0		0		0
Comprehensive loss attributable to Magnum Hunter Resources Corporation	1,888		-14,891		-3,017
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Wholly-Owned Guarantor Subsidiaries	'		'		'
Net income (loss)	-104,660		-49,600		-23,070
Foreign currency translation gain (loss)	0		0		0
Unrealized gain (loss) on available for sale investments	-84		-309		14
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	0		'		'
Comprehensive loss	-104,744		-49,909		-23,056
Comprehensive (income) loss attributable to non-controlling interests	0		0		0
Comprehensive loss attributable to Magnum Hunter Resources Corporation	-104,744		-49,909		-23,056
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'		'		'
Net income (loss)	-176,243		-28,754		9,236
Foreign currency translation gain (loss)	-10,928		3,883		-12,477
Unrealized gain (loss) on available for sale investments	0		0		0
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	0		'		'
Comprehensive loss	-187,171		-24,871		-3,241
Comprehensive (income) loss attributable to non-controlling interests	0		0		0
Comprehensive loss attributable to Magnum Hunter Resources Corporation	-187,171		-24,871		-3,241
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'		'		'
Net income (loss)	299,197		101,096		15,046
Foreign currency translation gain (loss)	0		0		0
Unrealized gain (loss) on available for sale investments	0		0		0
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	0		'		'
Comprehensive loss	299,197		101,096		15,046
Comprehensive (income) loss attributable to non-controlling interests	988		4,013		-249
Comprehensive loss attributable to Magnum Hunter Resources Corporation	300,185		105,109		14,797
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'		'		'
Net income (loss)	-223,164		-136,721		-76,412
Foreign currency translation gain (loss)	-10,928		3,883		-12,477
Unrealized gain (loss) on available for sale investments	8,178		-309		14
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	-8,262		'		'
Comprehensive loss	-234,176		-133,147		-88,875
Comprehensive (income) loss attributable to non-controlling interests	988		4,013		-249
Comprehensive loss attributable to Magnum Hunter Resources Corporation	($233,188)		($129,134)		($89,124)
[1]	Available for sale securities above includes $147,000 that has been classified as held for sale associated with the classification of the MHP subsidiary.
[2]	PRC Williston, LLC has been presented as a discontinued operation on a stand alone basis. Elimination entries have been recorded to eliminate discontinued operations treatment on a consolidated basis.

CONDENSED_CONSOLIDATING_GUARAN5

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 4) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2009
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	$111,711	$58,011	$33,838	'
Cash flow from investing activities	-127,860	-1,009,207	-361,715	'
Cash flow from financing activities	656	996,442	342,193	'
Effect of foreign exchange rate changes on cash	-417	-2,474	-19	'
Net change in cash and cash equivalents	-15,910	42,772	14,297	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	57,623	14,851	554	'
CASH AND CASH EQUIVALENTS, END OF YEAR	41,713	57,623	14,851	'
Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	111,711	58,011	33,838	'
Cash flow from investing activities	-127,860	-1,009,207	-361,715	'
Cash flow from financing activities	656	996,442	342,193	'
Effect of foreign exchange rate changes on cash	-417	-2,474	-19	'
Net change in cash and cash equivalents	-15,910	42,772	14,297	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	57,623	14,851	'	554
CASH AND CASH EQUIVALENTS, END OF YEAR	41,713	57,623	14,851	554
Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	111,711	58,011	33,838	'
Cash flow from investing activities	-127,860	-1,009,207	-361,715	'
Cash flow from financing activities	656	996,442	342,193	'
Effect of foreign exchange rate changes on cash	-417	-2,474	-19	'
Net change in cash and cash equivalents	-15,910	42,772	14,297	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	57,623	14,851	'	554
CASH AND CASH EQUIVALENTS, END OF YEAR	41,713	57,623	14,851	554
Magnum Hunter Resources Corporation | Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	-371,351	-458,921	-203,251	'
Cash flow from investing activities	422,303	-364,045	-90,464	'
Cash flow from financing activities	-29,929	831,080	310,917	'
Effect of foreign exchange rate changes on cash	0	0	0	'
Net change in cash and cash equivalents	21,023	8,114	17,202	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	26,872	18,758	'	1,556
CASH AND CASH EQUIVALENTS, END OF YEAR	47,895	26,872	18,758	1,556
Magnum Hunter Resources Corporation | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	-371,351	-458,921	-203,251	'
Cash flow from investing activities	422,303	-364,045	-90,464	'
Cash flow from financing activities	-29,929	831,080	310,917	'
Effect of foreign exchange rate changes on cash	0	0	0	'
Net change in cash and cash equivalents	21,023	8,114	17,202	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	26,872	18,758	'	1,556
CASH AND CASH EQUIVALENTS, END OF YEAR	47,895	26,872	18,758	1,556
PRC Williston, Inc. | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	-1,932	1,256	-1,738	'
Cash flow from investing activities	15,236	-49	-175	'
Cash flow from financing activities	-13,304	-1,207	1,913	'
Effect of foreign exchange rate changes on cash	0	0	0	'
Net change in cash and cash equivalents	0	0	0	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	0	0	'	0
CASH AND CASH EQUIVALENTS, END OF YEAR	0	0	0	0
Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	376,129	275,914	136,974	'
Cash flow from investing activities	-387,660	-277,965	-136,489	'
Cash flow from financing activities	-946	-1,966	-310	'
Effect of foreign exchange rate changes on cash	0	0	0	'
Net change in cash and cash equivalents	-12,477	-4,017	175	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	-4,462	-445	'	-620
CASH AND CASH EQUIVALENTS, END OF YEAR	-16,939	-4,462	-445	-620
Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	397,213	281,782	138,855	'
Cash flow from investing activities	-411,473	-287,204	-141,954	'
Cash flow from financing activities	796	1,781	3,206	'
Effect of foreign exchange rate changes on cash	0	0	0	'
Net change in cash and cash equivalents	-13,464	-3,641	107	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	-4,187	-546	'	-653
CASH AND CASH EQUIVALENTS, END OF YEAR	-17,651	-4,187	-546	-653
Non Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	106,933	241,018	100,115	'
Cash flow from investing activities	-162,503	-367,197	-134,762	'
Cash flow from financing activities	31,531	167,328	31,586	'
Effect of foreign exchange rate changes on cash	-417	-2,474	-19	'
Net change in cash and cash equivalents	-24,456	38,675	-3,080	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	35,213	-3,462	'	-382
CASH AND CASH EQUIVALENTS, END OF YEAR	10,757	35,213	-3,462	-382
Non Guarantor Subsidiaries | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	101,085	235,104	98,048	'
Cash flow from investing activities	-153,926	-357,912	-129,111	'
Cash flow from financing activities	29,789	163,581	28,070	'
Effect of foreign exchange rate changes on cash	-417	-2,474	-19	'
Net change in cash and cash equivalents	-23,469	38,299	-3,012	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	34,938	-3,361	'	-349
CASH AND CASH EQUIVALENTS, END OF YEAR	11,469	34,938	-3,361	-349
Eliminations | Debt Securities Under Universal Shelf Registration Statement Form S-3	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	0	0	0	'
Cash flow from investing activities	0	0	0	'
Cash flow from financing activities	0	0	0	'
Effect of foreign exchange rate changes on cash	0	0	0	'
Net change in cash and cash equivalents	0	0	0	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	0	0	'	0
CASH AND CASH EQUIVALENTS, END OF YEAR	0	0	0	0
Eliminations | Debt Securities Under Universal Shelf Registration Statement Form S-4	'	'	'	'
Schedule of condensed consolidating statements of cash flows	'	'	'	'
Cash flow from operating activities	-13,304	-1,210	1,924	'
Cash flow from investing activities	0	3	-11	'
Cash flow from financing activities	13,304	1,207	-1,913	'
Effect of foreign exchange rate changes on cash	0	0	0	'
Net change in cash and cash equivalents	0	0	0	'
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR	0	0	'	0
CASH AND CASH EQUIVALENTS, END OF YEAR	$0	$0	$0	$0

SUBSEQUENT_EVENTS_Details

SUBSEQUENT EVENTS (Details) (Subsequent event, Natural Gas)	Dec. 31, 2013
	MMBTU
Swaps | Jan 2014 - Dec 2014	'
SUBSEQUENT EVENTS	'
Natural gas commodity derivatives contract units per day (MMBTU)	21,000
Price per unit	4.27
Swaps | Jan 2015 - Dec 2015	'
SUBSEQUENT EVENTS	'
Natural gas commodity derivatives contract units per day (MMBTU)	20,000
Price per unit	4.18
Ceilings purchased (call) | Jan 2014 - Dec 2014	'
SUBSEQUENT EVENTS	'
Natural gas commodity derivatives contract units per day (MMBTU)	6,000
Price per unit	5.5

SUBSEQUENT_EVENTS_Details_2

SUBSEQUENT EVENTS (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Apr. 02, 2012	Jan. 08, 2014	Jan. 08, 2014	Jun. 13, 2013
In Millions, except Share data, unless otherwise specified	Series A Preferred Stock	Series A Preferred Stock	Eureka Hunter Holdings, LLC	Subsequent event	Subsequent event	Subsequent event
			Series A Preferred Stock	Restricted shares	Restricted shares	Eureka Hunter Holdings, LLC
				Officers, executives, and employees	Directors	Series A Preferred Stock
SUBSEQUENT EVENTS	'	'	'	'	'	'
Grants (in shares)	'	'	'	1,312,575	'	'
Vesting rights (as a percent)	'	'	'	33.00%	100.00%	'
Vesting period (in years)	'	'	'	'3 years	'1 year	'
Granted (in shares)	'	'	'	'	123,798	'
Preferred Stock, shares issued	9,885,048	7,672,892	622,641	'	'	97,492
Value of common units issued related to acquisitions	'	'	$12.50	'	'	$1.90

SUBSEQUENT_EVENTS_Details_3

SUBSEQUENT EVENTS (Details 3) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Jan. 21, 2014
In Millions, unless otherwise specified	Senior Revolving Credit Facility	Senior Revolving Credit Facility	Eureka Hunter Pipeline, LLC second lien term loan
			Master Loan and Security Agreement [Member]
			Subsequent event
SUBSEQUENT EVENTS	'	'	'
Principal amount	'	'	$5.60
Interest rate (as a percent)	3.56%	3.56%	7.94%
Term of debt instrument	'	'	'48 months

SUBSEQUENT_EVENTS_Details_5

SUBSEQUENT EVENTS (Details 5) (Subsequent event, USD $)	0 Months Ended
In Millions, except Share data, unless otherwise specified	Jan. 28, 2014	Jan. 10, 2014	Jan. 28, 2014	Dec. 31, 2013
	Eagle Ford Shale Assets	Settled Litigation	Senior Revolving Credit Facility	Senior Revolving Credit Facility
		Omnibus Settlement Agreement and Release [Member]	Third Amended and Restated Credit Agreement [Member]	Third Amended and Restated Credit Agreement [Member]
			Eagle Ford Shale Assets	Eagle Ford Shale Assets
SUBSEQUENT EVENTS	'	'	'	'
Settlement agreement percentage	'	50.00%	'	'
Cash consideration received	$15	'	'	'
Consideration received, number of shares of common stock received	65,650,000	'	'	'
Noncash or Part Noncash Divestiture, Amount of Consideration Received	9.5	'	'	'
Noncash Divestiture, Reduction of Debt	'	'	10	'
Line of Credit Facility, Current Borrowing Capacity	'	'	'	$232.50